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1
Bayreuther, Moritz, Jamin Cristall, and Felix J. Herrmann. "Curvelet denoising of 4d seismic." European Association of Geoscientists and Engineers, 2004. http://hdl.handle.net/2429/453.
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With burgeoning world demand and a limited rate of discovery of new reserves, there is increasing impetus upon the industry to optimize recovery from already existing fields. 4D, or time-lapse, seismic imaging is an emerging technology that holds great promise to better monitor and optimise reservoir production. The basic idea behind 4D seismic is that when multiple 3D surveys are acquired at separate calendar times over a producing field, the reservoir geology will not change from survey to survey but the state of the reservoir fluids will change. Thus, taking the difference between two 3D surveys should remove the static geologic contribution to the data and isolate the timevarying fluid flow component. However, a major challenge in 4D seismic is that acquisition and processing differences between 3D surveys often overshadow the changes caused by fluid flow. This problem is compounded when 4D effects are sought to be derived from vintage 3D data sets that were not originally acquired with 4D in mind. The goal of this study is to remove the acquisition and imaging artefacts from a 4D seismic difference cube using Curvelet processing techniques.
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Amini, Hamed. "A pragmatic approach to simulator-to-seismic modelling for 4D seismic interpretation." Thesis, Heriot-Watt University, 2014. http://hdl.handle.net/10399/2756.
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Borgan, Yngve. "Using the Composite Likelihood Method on 4D AVA Seismic Data." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for matematiske fag, 2011. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-13577.
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This thesis is concerned with 4D AVA seismic inversion problems. By comparing two seismic surveys done over the same area, but at different times, one hopes to discover untapped pockets of oil or gas. Using the full likelihood to analyse 4D AVA seismic data is impossible in practice due to memory and computational restrictions. The goal of the thesis is to find a useful framework for parameter estimation and predictions for 4D AVA seismic data, and the composite likelihood is introduced as a possible solution. The composite likelihood method takes in pairs of data points and sums over them instead of taking in all the data as is the case for the full likelihood. This makes calculations fast while avoiding matrix operations on large matrices.The composite likelihood method is tested on a data set from the Norne field for parameter estimations and predictions. Eight variations of the model are tested, the variations being the exponential or Matern correlation function, one or two data columns used as a data point in the composite likelihood, and a simple or wavelet convoluted noise term. The composite likelihood method is shown to perform well; it is fast and the estimates found agree well with previous experience. Comparison of the different models indicate that the choice of correlation function has little effect on the results, that the noise term should be kept simple, and that it is sufficient to use one data column.
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Rangel, Gonzalez Ricardo Elias. "The impact of shale pressure diffusion on 4D seismic interpretation." Thesis, Heriot-Watt University, 2016. http://hdl.handle.net/10399/3176.
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Shale typically has a low but non-negligible permeability of the order of nanodarcys (recognized an appreciated in production of unconventional resources), which could affect the magnitude and pattern of the pressure in conventional reservoirs over the lifetime of a producing field. The implications of this phenomenon for reservoir monitoring by 4D seismic can be significant, but depend on the geology of the field, the time-lines for production and recovery, and the timing of the seismic surveys. In this PhD thesis I developed an integrated workflow to assess the process of shale pressure diffusion and its elastic implications in the 4D seismic interpretation of four conventional reservoirs (three North Sea case studies and one from West Africa), with different geological settings (shallow marine and turbidites) and production mechanisms. To accomplish that, first, a detailed petrophysical evaluation was performed to characterize the overburden, intra-reservoir and underburden shales. Next, the simulation models were adjusted to activate the shale-related contributions, and then, applying simulator to seismic workflows, 3D and 4D synthetic seismic modelling were performed, for comparison with the observed seismic data and to establish the impact of the shale pressure diffusion in the elastic dynamic behaviour of the reservoir. This work also includes a case study where evaluation of shale pressure diffusion was integrated with geomechanical simulations to assess the propagation of time shifts and time strain in the overburden of a high pressure/high temperature reservoir under compaction, improving the understanding of the distribution and polarity of the observed seismic time strain. Fluid flow simulation results of this work indicate that activation of the shale improves the overall reservoir connectivity, enhancing model prediction (production history matched data). The fit to observed 4D seismic data was improved in all the field applications with a noticeable reduction (up to 6%) in the mismatch (hardening and softening signal distribution) for the models with active shales. In reservoirs where the saturation was very sensitive to changes in pressure, shale activation proved to impact strongly on the breakout and distribution of gas liberated from solution. Overall, this work found that inclusion of shale in the 3D and 4D reservoir seismic modelling can provide valuable insights for the interpretation of the reservoir’s dynamic behaviour and that, under particular conditions such as strong reservoir compartmentalization, shale pressure diffusion could be a significant process in the interpretation of the 4D seismic signature.
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Wu, Jianbing. "4D seismic and multiple-point pattern data integration using geostatistics /." May be available electronically:, 2007. http://proquest.umi.com/login?COPT=REJTPTU1MTUmSU5UPTAmVkVSPTI=&clientId=12498.
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Kazemi, Alireza. "Optimal parameter updating and appropriate 4D seismic normalization in seismic history matching of the Nelson field." Thesis, Heriot-Watt University, 2011. http://hdl.handle.net/10399/2474.
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History matching of reservoirs is very important in the oil industry because the simulation model is an important tool that can help with management decisions and planning of future production strategies. Nowadays, time-lapse (4D) seismic data is very useful for better capturing the fluid displacement in the reservoir, especially between wells. It is now common to integrate 4D seismic with production data in order to constrain the simulation model to both types of data. This thesis is based on a technique for automatic production and seismic history matching of reservoirs by. This technique integrates various tools such as streamline simulation, parameterization via pilot points and Kriging and geo-body updating, a petro-elastic model and the neighborhood algorithm, all in an automatic framework. All studies in this thesis are applied to the Nelson field but the approaches used here can be applied to any similar field. The history matching aim was to identify shale volumes and their distribution by updating three reservoir properties, net:gross, horizontal and vertical permeability. All history matching studies were performed in a six years production period, with baseline and one monitor seismic survey available, and then a forecast of the following three years was made with a second monitor for comparison. Various challenges are addressed in this thesis. We introduce a streamline guide approach in order to efficiently select the regions in the reservoir that have a strong influence on production activity of the wells and 4D seismic signature. Updating was performed more effectively compared to an approach where parameters were changed everywhere in the vicinity of the wells. Then, three parameter updating schemes are introduced to effectively combine various reservoir parameters in order to capture correctly the flow behaviour. The observed 4D seismic data used in this study consisted of relative pseudo-impedance with a different unit compared to synthetic impedance data. This challenge was addressed by introducing normalization. 4D predictions in the vertical well locations and full field simulation cells used in the normalization study and we observed different level of signal/noise ratio in normalized observed 4D maps at the end of study. We include the normalized 4D maps in history matching of the field and we observed that normalization very important. We also compared the seismic and production history matching studies with a case where seismic was not included in history matching (production history matching). The results show that if 4D data is normalized appropriately, the reduction of both seismic and production misfits is better than the production only history matching case.
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Wright, Richard James. "4D seismic analysis of the Hibernia oil field, Grand Banks, Canada /." Internet access available to MUN users only:, 2004. http://collections.mun.ca/u?/theses,16342.
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Tian, Sean (Shuzhe). "Closing the loop by engineering consistent 4D seismic to simulator inversion." Thesis, Heriot-Watt University, 2014. http://hdl.handle.net/10399/2931.
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The multi-disciplinary nature of closing the loop (CtL) between 4D seismic and reservoir engineering data requires integrated workflows to make sense of these different measurements. According to the published literatures, this integration is subject to significant inconsistency and uncertainty. To resolve this, an engineering consistent (EC) concept is proposed that favours an orderly workflow to modelling and inverting the 4D seismic response. Establishing such consistency facilitates a quantitative comparison between the reservoir model and the acquired 4D seismic data observation. With respect to the sim2seis workflow developed by Amini (2014), a corresponding inverse solution is proposed. The inversion, called seis2sim, utilises the model prediction as a priori information, searching for EC seismic answers in the joint domain between reservoir engineering and geophysics. Driven by a Bayesian algorithm, the inversion delivers more stable and certain elastic parameters upon application of the EC constraints. The seis2sim approach is firstly tested with a synthetic example derived from a real dataset before being applied to the Heidrun and Girassol field datasets. The two real data examples are distinctive from each other in terms of seismic quality, geological nature and production activities. After extracting the 3D and 4D impedance from the seismic data, CtL workflows are designed to update various aspects of the reservoir model according to the comparison between sim2seis and seis2sim. The discrepancy revealed by this cross-domain comparison is informative for robust updating of the reservoir model in terms reservoir geometry, volumetrics and connectivity. After applying tailored CtL workflows to the Heidrun and Girassol datasets, the statistical istributions of petrophysical parameters, such as porosity and NTG, as well as intra- and inter-connectivity for reservoir compartments are revised accordingly. Consequently, the 3D and 4D seismic responses of the reservoir models are assimilated with the observations, while the production match to the historical data is also improved . Overall, the proposed seis2sim and CtL workflows show a progression in the quantitative updating of the reservoir models using time-lapse seismic data.
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Fursov, Ilya. "Quantitative application of 4D seismic data for updating thin-reservoir models." Thesis, Heriot-Watt University, 2015. http://hdl.handle.net/10399/2968.
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A range of methods which allow quantitative integration of 4D seismic and reservoir simulation are developed. These methods are designed to work with thin reservoirs, where the seismic response is normally treated in a map-based sense due to the limited vertical resolution of seismic. The first group of methods are fast-track procedures for prediction of future saturation fronts, and reservoir permeability estimation. The input to these methods is pressure and saturation maps which are intended to be derived from time-lapse seismic attributes. The procedures employ a streamline representation of the fluid flow, and finite difference discretisation of the flow equations. The underlying ideas are drawn from the literature and merged with some innovative new ideas, particularly for the implementation and use. However my conclusions on the applicability of the methods are different from their literature counterparts, and are more conservative. The fast-track procedures are advantageous in terms of speed compared to history matching techniques, but are lacking coupling between the quantities which describe the reservoir fluid flow: permeabilities, pressures, and saturations. For this reason, these methods are very sensitive to the input noise, and currently cannot be applied to the real dataset with a robust outcome. Seismic history matching is the second major method considered here for integrating 4D seismic data with the reservoir simulation model. Although more computationally demanding, history matching is capable of tolerating high levels of the input noise, and is more readily applicable to the real datasets. The proposed implementation for seismic modelling within the history matching loop is based on a linear regression between the time-lapse seismic attribute maps and the reservoir dynamic parameter maps, thus avoiding the petro-elastic and seismic trace modelling. The idea for such regression is developed from a pressure/saturation inversion approach found in the literature. Testing of the seismic history matching workflow with the associated uncertainty estimation is performed for a synthetic model. A reduction of the forecast uncertainties is observed after addition of the 4D seismic information to the history matching process. It is found that a proper formulation of the covariance matrices for the seismic errors is essential to obtain favourable forecasts which have small levels of bias. Finally, the procedure is applied to a North Sea field dataset where a marginal reduction in the prediction uncertainties is observed for the wells located close to the major seismic anomalies. Overall, it is demonstrated that the proposed seismic history matching technique is capable of integrating 4D seismic data with the simulation model and increasing confidence in the latter.
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Maskeri, Yahya Amer. "Quantitative 4D seismic for the analysis of reservoir heterogeneity and connectivity." Thesis, Heriot-Watt University, 2005. http://hdl.handle.net/10399/216.
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Falahat, Reza. "Quantitative monitoring of gas injection, exsolution and dissolution using 4D seismic." Thesis, Heriot-Watt University, 2012. http://hdl.handle.net/10399/2559.
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The main concern in the monitoring of gas injection, exsolution and dissolution is the exact spatial distribution of the gas volumes in the subsurface. In principle, this concern is addressed by the use of 4D seismic data. However, it is recognised that the seismic response still largely provides a qualitative estimate of the moved subsurface fluids; exact quantitative evaluation of fluid distributions and associated saturations remains a challenge still to be solved. It is widely believed that a few percent of gas makes the pore fluid mixture very compressible, so that it cannot be distinguished from a more complete gas saturation using seismic techniques. However, because of the fact that a gas distribution viewed at the reservoir scale is distinctly different from that observed at the laboratory scale, conclusions from laboratory measurements may not, in fact, be wholly applicable. Indeed, it is found in this study that the main factor controlling the seismic response is gas thickness, whilst gas saturation per se remains approximately constant. Modelling studies show that, for thin reservoirs (less than tuning thickness), both timeshift and amplitude change attributes have a linear trend with gas volume. In theory, this conclusion does not apply to thick reservoirs, as the amplitude change then becomes non-linear. However, because thick reservoirs are normally combinations of intra reservoir sand and shale, it is anticipated that a linear amplitude response can still be expected in most reservoirs. Reservoir heterogeneity is observed to affect these results by less than 2%. In the modeling, a spurious deviation from linearity is evident with increasing simulation model cell size (especially the vertical dimension). The understanding above is applied to both timeshift and amplitude change attributes in a North Sea gas injection field. Here, seismic scale calibration coefficients are obtained by a volumetric method which aims to calculate gas volume maps using the 4D seismic attributes. The work reveals that the results from the two mapped attributes appear reasonably close but still have regions of disparity. Synthetic data based on the reservoir model and further analysis of the observed data have been able to replicate some of these differences and identify them as due to inter-layer wave interferences and 4D noise. Similar findings to the above also apply to gas exsolution, in which gas migrates after arriving at the critical gas saturation, and establishes two specific gas saturations in the ii reservoir: maximum gas saturation within the gas cap and critical or minimum gas saturation within the oil leg. On the other hand, for the reverse process, in which reservoir pressure builds up, it is noted that it is not only the fluid type that impacts the gas when it goes back into solution, but also other reservoir properties such as relative permeability curves, transmissibility, Kv/Kh, and the injection/production plan. The laboratory-proposed equations for calculation of solution gas oil ratio (Rs) and pressure dependency of the fluid and rock are found to be not directly valid in cases in which the reservoir pressure drops below the bubble point pressure. In this situation, gas evolves, migrates and alters the pressure dependency of the saturated rock and solution gas oil ratio. A compositional change of the gas and oil is found to occur with pressure drop. However, it is observed to have a negligible impact on the seismic domain. Finally, importance is drawn to the role of engineering principles when interpreting dynamic reservoir changes from 4D seismic data. In particular, it is found that, in clastic reservoirs, the principal parameters controlling mapped 4D signatures are not the pressure and saturation changes per se, but these changes scaled by the corresponding thickness (or pore volume) of the reservoir volume that these effects occupy. This understanding is validated both with numerical modelling and analytic calculation. This provides a basis for a linear equation that can readily and accurately be used to invert for pressure and saturation changes. The observed seismic data are then inverted for pressure and saturation changes using the principles above. The results show that the simulator does appear to predict the inverted seismic observations fairly accurately. However, there are also some noticeable differences which require some specific updates to the transmissibility multipliers (and hence barriers) and the net-to-gross distribution in the simulation model. This project reveals the ability of 4D seismic to quantitatively monitor the gas injection and exsolution, and highlights the fact that laboratory measures are not directly applicable at the reservoir scale. It can be concluded that the impact of the reservoir scale phenomena needs to be taken into account during time-lapse seismic interpretations.
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Briceño, Yañez Angel Eduardo. "Calibration and use of the petroelastic model for 4D seismic interpretation." Thesis, Heriot-Watt University, 2017. http://hdl.handle.net/10399/3300.
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One of the major objectives of 4D studies is to understand and quantify changes in the seismic response, related to pressure and saturation changes in the reservoir. A key ingredient of such interpretation is the petroelastic model (PEM), which links fluid saturations and pore pressure changes in the reservoir rock to the elastic property changes required for seismic modelling, time-lapse feasibility studies, 4D inversion and also seismic history matching. Many previous studies have pointed out the difficulty of selecting a PEM, the challenges in calibrating the model to the in situ response, and in particular the uncertainties involved. In this work I study the use of different deterministic PEMs for simulator to seismic modelling. The models are applied to three fields in the UKCS, Norwegian Sea and offshore Brazil with distinctly different geological settings. For each model, the static components are calibrated against a range of wireline log data acquired prior to production using an optimization algorithm. The dependence on pressure change is then added separately using coefficients derived from core data in the laboratory. All PEMs for the clastic datasets as well for the carbonate reservoir, are found to yield similar responses making the choice of the “best” challenging; however even when an appropriate well calibrated model is used, it may not be adequate for time-lapse seismic studies. In addition, the large number of input parameters for each model makes the process of model fitting particularly non-unique. To reduce the input parameters for computing the time lapse seismic response a linear two parameter equation has been suggested which gives similar results to the multi-parameter models, specifically for an oil-water system. When working with maps of 4D seismic attributes in particular, the work presented in this research advocate that a simple model which is linear with respect to the pressure and saturation changes, and is “primed” by any conventional deterministic PEM may be an adequate alternative for time-lapse seismic interpretation. The non-unique nature of the rock physics models, together with data and model uncertainties creates the need for time-consuming comparisons in the Seismic History Matching (SHM) workflow. This study presents a simple and interactive way of visualizing all of these uncertainties, whilst optimizing the SHM. It consists of a simple cross-plot of all changes in water saturation and pore pressure between at least two time periods of interest in the reservoir history (usually pre-production baseline and a monitor) from the simulation model and colour coded based with the 4D seismic signature from the “predicted” models or “observed” data. Therefore it allow us to discriminate between regions in the reservoir that are dominated by pressure or saturation, from which a boundary line associated with the controlling parameters (CP/CS) from the simplified proxy model PEM can be drawn. Application to synthetic examples and field datasets verified the usefulness of this approach and the sensitivities to both data and the model.
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Yan, Tianjiao. "History Matching of Production and 4D Seismic Data : - Application to the Norne Field." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2014. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-25276.
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History matching is the procedure to build a model as close as possible to nature. Reservoir models, constrained to seismic response, as well as flow response, can provide a better description of the reservoir and thus more reliable forecast. 4D seismic have the potential to provide the fluid contact with time, estimating the fault seal and locate the bypass fluids. This thesis focuses on history matching use production data and time-lapse seismic, with application to the Norne field in the Norwegian Sea.This work first describes a methodology for history matching. The parameters selected for study are permeability in x- and z-direction and fault transmissibility. The approach is manual and modified by trial and error procedure. Sensitivity analysis is applied before history matching. Results show the cumulative oil production profile has the great impact on permeability and fault transmissibility. Adjustment of permeability is used to track the oil near- and far from the wellbores and control the water movement between cells and to improve the water cut match. Fault transmissibilities are used to control the fluid flow direction and to guide the water flood.In the seismic interpretation study part, Time-lapse seismic surveys is used to qualitatively track the water-oil contact movement and helps to understand the flood direction. Time-lapse seismic surveys of the Norne field acquired in 2001 and 2004 is qualitaruvely used to test the accrurency of base case and modified simulation model.
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PERDOMO, PAUL RICHARD RAMIREZ. "4D SEISMIC, GEOMECHANICS AND RESERVOIR SIMULATION INTEGRATED STUDY APPLIED TO SAGD THERMAL RECOVERY." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2009. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=31856@1.
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PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIROAGÊNCIA NACIONAL DE PETRÓLEO
As reservas de óleos pesados têm obtido grande importância devido à diminuição das reservas de óleos leves e ao aumento dos preços do petróleo. Porém, precisa-se de aumentar a viscosidades destes óleos pesados para que possam fluir até superfície. Para reduzir a viscosidade foi escolhida a técnica de recuperação térmica SAGD (Steam Assisted Gravity Drainage) pelos seus altos valores de recobro. A redução da viscosidade é atingida pela transmissão de calor ao óleo pela injeção de vapor, porém uma parte deste calor é transmitida à rocha. Esta transmissão de calor junto com a produção de óleo geram uma variação no estado de tensões no reservatório o que por sua vez geram fenômenos geomecânicos. Os simuladores convencionais avaliam de uma forma muito simplificada estes fenômenos geomecânicos, o que faz necessários uma abordagem mais apropriada que acople o escoamento dos hidrocarbonetos e a transmissão de calor com a deformação da rocha. As mudanças no reservatório, especialmente a variação da saturação, afetam as propriedades sísmicas da rocha, as quais podem ser monitoradas para acompanhar o avanço da frente de vapor. A simulação fluxo-térmica-composicional-geomecânica é integrada à sísmica de monitoramento 4D da injeção de vapor (a través da física de rochas). Existe uma grande base de dados, integrada por propriedades dos fluidos do reservatório (PVT) (usado no arquivo de entrada de simulação de fluxo) e uma campanha de mecânica das rochas. Foram simulados vários cenários geomecânicos considerando a plasticidade e variação da permeabilidade. Foram avaliadas várias repostas geomecânicas e de propriedades de fluidos no pico de pressão e final do processo SAGD. A resposta geomecânica pode ser observada, porém foi minimizada devido à baixa pressão de injeção, sendo o mecanismo de transmissão de calor um fator importante na produção de óleo (pela redução da viscosidade) e a separação vertical entre poços. Foi também significativa à contribuição da plasticidade no aumento da produção de hidrocarbonetos. A impedância acústica foi calculada usando a Equação de substituição de fluidos de Gassmann. Os sismogramas sintéticos de incidência normal (para monitorar o avanço da frente o câmara de vapor) mostraram a área afetada pela injeção de vapor, porém com pouca variação devida principalmente à rigidez da rocha.
The heavy oil reserves have gained importance due to the decreasing of the present light oil reserves. Although it is necessary to reduce the oil viscosity and makes it flows to surface. For its high recovery factor the SAGD (Steam Assited Gravity Drainage) thermal process was selected. The viscosity reduction is achieved by heat transfer from steam to oil, but some part of this heat goes to rock frame. This heat transfer together with oil production change the initial in-situ stress field what creates geomechanical effects. The conventional flux simulators have a very simplified approach of geomechanical effects, so it is necessary to consider a more suitable approach that considers the coupling between oil flux and heat transfer with rock deformation. The changes within the reservoir, specially the saturation change, affect the seismical rock properties which can be used to monitor the steam chamber growth. The flux-thermal geomechanics is integrated to steam chamber monitoring 4D seismic (through the rock physics). There is a great data base, integrated by reservoir fluid properties (PVT) (used in reservoir simulation dataset) and a rock mechanics campaign. Several scenaries were simulated considering the plasticity and permeability variation. Several geomechanical responses and flux properties at peak pressure and end of SAGD process were evaluated. The geomechanical response can be observed, but was minimized due to low steam injection pressure, being the heat transfer an important in oil production (for the viscosity reduction) and the vertical well separation, too. The plasticity has a significant contribution in the increment of oil production. Acoustic impedance was calculated by using Gassmann fluid substitution approach. 2D Synthetic seismograms, normal incidence (to monitor the steam camera front advance), showed the area affected by steam injection, but with little variation due principally to rock stiffness.
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Hodgson, Neil. "Inversion for reservoir pressure change using overburden strain measurements determined from 4D seismic." Thesis, Heriot-Watt University, 2009. http://hdl.handle.net/10399/2320.
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When significant pore pressure changes occur because of production from a hydrocarbon reservoir the rocks both inside and outside of the reservoir deform. This deformation results in traveltime changes between reflection events on timelapse seismic data, because the distance between reflection events is altered and the seismic velocity changes with the strain. These traveltime differences are referred to as time-lapse time shifts. In this thesis, time-lapse time shifts observed in the overburden are used as an input to a linear inversion for reservoir pressure. Measurements from the overburden are used because, in general, time shift estimates are more stable, the strain deformations can be considered linear, and fluid effects are negligible, compared to the reservoirlevel signal. A critical examination of methods currently available to measure time-lapse time shifts is offered. It is found that available methods are most accurate when the time shifts are slowly varying with pressure and changes in the seismic reflectivity are negligible. While both of these conditions are generally met in the overburden they are rarely met at reservoir level. Next, a geomechanical model that linearly relates the overburden time-lapse time shifts to reservoir pressure is considered. This model takes a semi-analytical approach by numerical integration of a nucleus of strain in a homogeneous poroelastic halfspace. Although this model has the potentially limiting assumption of a homogenous medium, it allows for reservoirs of arbitrary geometries, and, in contrast to the complex numerical approaches, it is simple to parameterise and compututationally efficient. This model is used to create a linear inversion scheme which is first tested on synthetic data output from complex finite-element model. Despite the simplifications of the i inversion operator the pressure change is recovered to within ±10% normalised error of the true pressure distribution. Next, the inversion scheme is applied to two real data cases in different geological settings. First to a sector of the Valhall Field, a compacting chalk reservoir in the Norwegian Sea, and then the Genesis Field, a stacked turbidite in the Gulf of Mexico. In both cases the results give good qualitative matches to existing reservoir simulator estimates of compaction or pressure depletion. It is possible that updating of the simulation model may be assisted by these results. Further avenues of investigation are proposed to test the robustness of the simplified geomechanical approach in the presence of more complex geomechanical features such as faults and strong material contrasts.
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Omofoma, Veronica Ehinome Ebiweni. "The quantification of pressure and saturation changes in clastic reservoirs using 4D seismic data." Thesis, Heriot-Watt University, 2017. http://hdl.handle.net/10399/3394.
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The problem of quantifying pressure and saturation changes from 4D seismic data is an area of active research faced with many challenges concerning the non-uniqueness of seismic data inversion, non-repeatability noise in the data, the formulation of the inverse problem, and the use of appropriate constraints. The majority of the inversion methods rely on empirical rock-physics model calibrations linking elastic properties to expected pressure and saturation changes. Model-driven techniques indeed provide a theoretical framework for the practical interpretation of the 4D seismic response but pressure and saturation separation based on this approach are inconsistent with the observed 4D seismic response and insights from reservoir engineering. The outcome is a bias in estimated pressure and saturation changes and for some a leakage between the two. Others have addressed some of this bias using the causality between the induced-production and the observed 4D seismic response to formulate a direct, quick and less compute-intensive inversion - characterised by data-driven techniques. But challenges still remain as to the accuracy of the causality link- as defined by the reservoir's sensitivity to production effects, and in defining appropriate constraints to tackle non-uniqueness of the seismic inversion and uncertainties in the 4D seismic data. The main contributions of this thesis are the enhancement of data-driven inversion approach by using multiple monitor 4D seismic data to quantify the reservoir's sensitivity to pressure and saturation changes, together with the introduction of engineering-consistent constraints provided by multiple history-matched fluid-flow simulation models. A study using observed 4D seismic data (amplitudes and times shifts) acquired at different monitor times on four producing North Sea clastic fields demonstrates the reliability of the seismic-based method to decouple the reservoir's sensitivity specific to each field's geological characteristics. A natural extension is to combine multiple monitor 4D seismic data in an inversion scheme that solves for the reservoir sensitivity to pressure and saturation changes, the pressure and saturation changes themselves and the uncertainties in the inversion solution. At least two monitor 4D seismic datasets are required to solve for the reservoir's sensitivity, and offset stacks (near, mid, and far) are required to decouple pressure, water and gas saturation changes. The generation and use of geologically-constrained and production-constrained multiple simulation models provided spatial constraints to the solution space, making the inversion scheme robust. Within the inversion, the fitness to spatial historical data, i.e. 4D seismic data acquired at different monitor times is analysed. The added benefit of using multiple monitor data is that it allows for a soft 'close-the-loop' between the engineering and the 4D seismic domain. One step in the inversion scheme is repeated for as many history-matched simulation models as generated. Each model provides pressure and saturation input to the inversion to obtain maps of the reservoir's sensitivity. By computing the norm of residuals for each inversion based on each model input, the best model (having the lowest norm of residuals) can be identified, besides the use of a history-matching objective. The inversion scheme thus marks the first step for a seismic-assisted history matching procedure, suggesting that pressure and saturation inversion is best done within the history-matching process. In addition, analysis of uncertainties in quantitative 4D seismic data interpretation is performed by developing a seismic modelling method that links the shot timings of a real field towed streamer and a permanent reservoir monitoring (PRM) acquisition to the reservoir under production. It is found that pressure and saturation fluctuations that occur during the shooting of monitor acquisitions creates a complicated spatio-temporal imprint on the pre-stack data, and errors if 4D seismic data is analysed in the post-stack domain. Pressure and saturation changes as imaged across the offset stacks (near, mid and far offset) are not the same, adding to the problems in separating pressure and saturation changes using offset stacks of 4D seismic data. The approximate modelling relay that the NRMS errors between offset stacks (up to 7.5%) caused by the intra-survey effects are likely at the limit of 4D seismic measurements using towed streamer technology, but are potentially observable, particularly for PRM technology. Intra-survey effects should thus be considered during 4D survey planning as well as during data processing and analysis. It is recommended that the shot timestamps of the acquisition is used to sort the seismic data immediately after pre-stack migration and before any stacking. The seismic data should also be shot quickly in a consistent pattern to optimise time and fold coverage. It is common to relate the simulation model output to a specific time within the acquisition (start, middle or end of survey), but this study reveals that it is best to take an average of simulation model predictions output at fine time intervals over the entire length of the acquisition, as this is a better temporal comparison to the acquired post-stack 4D seismic data.
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Dehghannejad, Mahdieh. "Reflection seismic investigation in the Skellefte ore district : A basis for 3D/4D geological modeling." Doctoral thesis, Uppsala universitet, Geofysik, 2014. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-221225.
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The Skellefte ore district in northern Sweden is a Palaeoproterozoic volcanic arc and one of the most important ones hosting volcanogenic massive sulfide (VMS) deposits, producing mainly base metals and orogenic gold deposits. Due to high metal prices and increased difficulties in finding shallow deposits, the exploration for and exploitation of mineral resources is quickly being moved to greater depths. For this reason, a better understanding of the geological structures in 3D down to a few kilometers depth is required as a tool for ore targeting. As exploration and mining go deeper, it becomes more and more evident why a good understanding of geology in 3D at exploration depths, and even greater, is important to optimize both exploration and mining. Following a successful pilot 3D geological modeling project in the western part of the district, the Kristineberg mining area, a new project "VINNOVA 4D modeling of the Skellefte district" was launched in 2008, with the aim of improving the existing models, especially at shallow depth and extending the models to the central district. More than 100 km of reflection seismic (crooked) profiles were acquired, processed and interpreted in conjunction with geological observations and potential field data. Results were used to constrain the 3D geological model of the study area and provided new insights about the geology and mineral potential at depth. Results along the seismic profiles in the Kristineberg mining area proved the capability of the method for imaging reflections associated with mineralization zones in the area, and we could suggest that the Kristineberg mineralization and associated structures dip to the south down to at least a depth of about 2 km. In the central Skellefte area, we were able to correlate main reflections and diffractions with the major faults and shear zones. Cross-dip analysis, reflection modeling, pre-stack time migration, swath 3D processing and finite-difference seismic modeling allowed insights about the origin of some of the observed reflections and in defining the imaging challenges in the associated geological environments.VINNOVA 4D modeling of the Skellefte district
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Yuh, Sung H. "Time-lapse seismic monitoring of subsurface fluid flow." [College Station, Tex. : Texas A&M University, 2004. http://hdl.handle.net/1969.1/430.
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Sagitov, Ildar. "Adequate model complexity and data resolution for effective constraint of simulation models by 4D seismic data." Thesis, Heriot-Watt University, 2014. http://hdl.handle.net/10399/2754.
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4D seismic data bears valuable spatial information about production-related changes in the reservoir. It is a challenging task though to make simulation models honour it. Strict spatial tie of seismic data requires adequate model complexity in order to assimilate details of seismic signature. On the other hand, not all the details in the seismic signal are critical or even relevant to the flow characteristics of the simulation model so that fitting them may compromise the predictive capability of models. So, how complex should be a model to take advantage of information from seismic data and what details should be matched? This work aims to show how choices of parameterisation affect the efficiency of assimilating spatial information from the seismic data. Also, the level of details at which the seismic signal carries useful information for the simulation model is demonstrated in light of the limited detectability of events on the seismic map and modelling errors. The problem of the optimal model complexity is investigated in the context of choosing model parameterisation which allows effective assimilation of spatial information in the seismic map. In this study, a model parameterisation scheme based on deterministic objects derived from seismic interpretation creates bias for model predictions which results in poor fit of historic data. The key to rectifying the bias was found to be increasing the flexibility of parameterisation by either increasing the number of parameters or using a scheme that does not impose prior information incompatible with data such as pilot points in this case. Using the history matching experiments with a combined dataset of production and seismic data, a level of match of the seismic maps is identified which results in an optimal constraint of the simulation models. Better constrained models were identified by quality of their forecasts and closeness of the pressure and saturation state to the truth case. The results indicate that a significant amount of details in the seismic maps is not contributing to the constructive constraint by the seismic data which is caused by two factors. First is that smaller details are a specific response of the system-source of observed data, and as such are not relevant to flow characteristics of the model, and second is that the resolution of the seismic map itself is limited by the seismic bandwidth and noise. The results suggest that the notion of a good match for 4D seismic maps commonly equated to the visually close match is not universally applicable.
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Msolo, Andile Lucky. "4D seismic analysis: discriminating between saturation and pressure changes form a data acquired Offshore Equatorial Guinea." Master's thesis, University of Cape Town, 2017. http://hdl.handle.net/11427/25501.
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4D seismic analysis is used to understand the performance of a producing oil field in order to increase production and mitigate risk. This is done by interpreting changes in water saturation and changes in effective pressure in the reservoir, which allows production to be maximized safely. In this project, I determined saturation and pressure changes in an oil field offshore Equatorial Guinea. I used Landrø's technique as a basis for the analysis, however Landrø's technique requires the presence of reservoir samples. For this project, rock samples of the reservoir were not available; this led me to modify Landrø's methodology using approximations based on well-accepted rock physics relationships. I tested this new methodology on a synthetic model, which gave encouraging results, after which it was applied to real seismic data. Pressure and saturation changes estimated in the reservoir indicate that the northern part of the reservoir experienced a decrease in pore pressure. The saturation changes over the northern part of the reservoir are not prominent. The central and southern parts of the reservoir show an increase in water saturation accompanied by an increase in pore pressure. The results are consistent with the production and injection history of this area. A comparison between saturation before production, saturation changes after production and pressure changes after production indicates an area (on the northern part of the reservoir) which shows fluid anomalies before production and does not show any production (or 4D) effects. New production wells could potentially be drilled in this area to increase production.
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Souza, Rafael Medeiros de. "Obtenção de dados de saturação e pressão a partir de atributos derivados da sísmica 4D." [s.n.], 2010. http://repositorio.unicamp.br/jspui/handle/REPOSIP/263743.
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Orientador: Denis José SchiozerDissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica e Instituto de Geociências
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Resumo: A utilização de dados de produção para o aumento da confiabilidade das previsões de produção de um campo apresenta limitações, principalmente no início do seu desenvolvimento, quando há menos dados observados e as incertezas sãomaiores. Uma alternativa para a melhora da qualidade do modelo é a utilização de mapas de saturação e pressão obtidos a partir da sísmica 4D. A incorporação destas informações ainda é pouco explorada em estudos de engenharia de reservatórios e possui grande potencial para diminuição das incertezas causadas pela falta de informação e complexidade de um campo de petróleo. Trabalhos recentes indicam que a forma ideal de se utilizar esta informação na calibração de modelos numéricos de reservatórios é convertê-la em saturação e pressão. Assim, o objetivo deste estudo é avaliar a obtenção, a partir de dados da sísmica 4D, das distribuições de saturação e pressão ao longo de reservatórios de petróleo. A metodologia proposta envolve a definição de dois métodos. No Método 1, a saturação é obtida implicitamente, por meio de um processo de inversão vinculado a dados de engenharia de reservatórios e a pressão é explicitamente obtida com a aplicação deste mapa de saturação em um processo de ajuste de histórico integrado (SOUZA et al., 2010). Este método foi aplicado em um modelo five-spot com duas falhas geológicas e um canal de alta permeabilidade. Os mapas de saturação e pressão obtidos indicam claramente as estruturas do reservatório que definem as tendências de fluxo de fluídos. Estes resultados indicam que o método iterativo mostrou-se eficaz em face às dificuldades de se modelar o comportamento da resposta acústica do reservatório. Além disso, destaca-se o uso de informações da simulação de reservatórios, como ajuste das vazões de líquidos e a abordagem iterativa entre a inversão e o processo de ajuste com o intuito de desacoplar as contribuições da saturação e pressão na composição da resposta acústica do reservatório. No Método 2, mapas de saturação e pressão são obtidos simultaneamente por meio do processo de inversão vinculado a dados de engenharia. Este método foi aplicado em um modelo do Campo de Namorado modificado. Este método permitiu a obtenção dos mapas de saturação e pressão simultaneamente e através deles foi possível identificar as principais estruturas que podem definir as tendências de fluxo no reservatório, como as falhas geológicas e canais de alta permeabilidade presentes. Dentre as principais contribuições deste estudo estão à definição de uma metodologia capaz de estimar saturação e pressão a partir de atributos sísmicos, o desenvolvimento de vínculos, baseados na engenharia de petróleo, aplicados ao processo global
Abstract: The use of production data for increasing the reliability of production forecasts of a field is limited, especially in early development, when there are fewer observed data and the uncertainties are greater. An alternative to improve the quality of the model is the use of saturation and pressure maps obtained from time-lapse seismic. The incorporation of this information is not explored in reservoir engineering studies and hás great potential for reducing uncertainties caused by lack of information and complexity of oil fields. Recent work indicates that the best way to use this information to calibrate numerical models of reservoirs is to convert it to saturation and pressure. Thus, the objective of this study is to obtain, from time-lapse seismic data, the distributions of saturation and pressure over oil reservoirs. The presented methodology consists of the definition of two methods. In Method 1, the saturation is implicitly obtained through an inversion process constrained by reservoir engineering data. Thus, the pressure is explicitly obtained with the application of map saturation in the history matching process (SOUZA et al., 2010). This method was applied to a five-spot model with two faults and a high permeability channel. The saturation and pressure maps obtained clearly indicate the reservoir structures that define fluid flow trends in the reservoir. These results indicate that the iterative method was effective to overcome pressure modeling difficulties in the reservoir acoustic response. Furthermore, it's highlighted the use of reservoir simulation information, such as the well liquid rate matching and the iterative approach between the inversion and matching process in order to decouple the contributions of saturation and pressure in the reservoir acoustic response composition. In Method 2, the saturation and pressure maps are obtained simultaneously through the inversion process constrained by engineering data. This method was applied to a modified model of the "Namorado Field" (Campos Basin, Brazil), that hás geological faults and high permeability channels. It was also necessary to apply na empirical modeling of the rock bulk modules as pressure functions (EMERICK, 2007). This improved the reservoir acoustic sensitivity and allowed, together with the engineering data constraints, obtain these maps. It was possible to identify the main structures that can set fluid flow trends in the reservoir.As major contributions of this study are the developments of a methodology able to provide saturation and pressure trends regarding time-lapse data and engineering data constraints to the overall process
Mestrado
Reservatórios e Gestão
Mestre em Ciências e Engenharia de Petróleo
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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.
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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
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Castro, Scarlet A. "A probabilistic approach to jointly integrate 3D/4D seismic, production data and geological information for building reservoir models /." May be available electronically:, 2007. http://proquest.umi.com/login?COPT=REJTPTU1MTUmSU5UPTAmVkVSPTI=&clientId=12498.
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Davólio, Alessandra 1980. "Using reservoir simulation to constrain the estimation of dynamic properties from 4D seismic = Uso da simulação de reservatórios para restringir a estimativa de propriedades dinâmicas a partir da sísmica 4D." [s.n.], 2013. http://repositorio.unicamp.br/jspui/handle/REPOSIP/263761.
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Orientadores: Denis José Schiozer, Célio MaschioTese (doutorado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica e Instituto de Geociências
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Resumo: O foco deste trabalho é usar dados de engenharia de reservatórios gerados através da simulação de fluxos para melhorar a interpretação quantitativa da sísmica 4D. A ideia é usar os conhecimentos de engenharia para minimizar possíveis informações incorretas geradas pela sísmica 4D, antes de usá-la para atualizar modelos de simulação de reservatórios em um procedimento de ajuste de histórico. Neste trabalho a integração entre estes dois conjuntos de dados é feita no domínio da pressão e saturação. Dessa forma, a primeira parte do trabalho apresenta uma metodologia para estimar variações de pressão e saturação a partir da sísmica 4D através de um procedimento de inversão petro-elástica. Este procedimento pode ser visto como uma ferramenta para aplicar a metodologia de integração da segunda parte, que é uma das principais contribuições deste trabalho. A metodologia de integração usa múltiplos modelos de simulação para restringir a estimativa de pressão e saturação a partir da sísmica 4D. Como resultado, observaram-se mapas menos ruidosos que permitem, portanto, uma melhor interpretação das variações ocorridas no reservatório. Seguindo a sequencia tradicional de trabalho, o mapa de saturação estimado foi então usado como dado de entrada em um processo de ajuste de histórico apresentado na terceira parte da tese. Foi mostrado que o procedimento de ajuste gera melhores resultados quando o dado de entrada, neste caso mapa de saturação, respeita o balanço de massa, o que não acontecia para os dados considerados. Assim, uma metodologia para calibrar o volume de água injetada associado ao mapa de saturação gerado pela sísmica 4D é apresentada na última parte do trabalho, que é outra contribuição importante a se destacar. Para melhor controlar os resultados de todas as metodologias aqui apresentadas foram usados dados sintéticos em todo o trabalho. Embora resultados satisfatórios tenham sido observados para este conjunto de dados, é importante destacar que as principais contribuições deste trabalho não são apenas os resultados observados, mas as metodologias propostas, que apresentam uma perspectiva inovadora para integração entre dados de sísmica 4D e engenharia de reservatórios
Abstract: The focus of this work is to use reservoir engineering data from numerical flow simulation to improve the quantitative interpretation of 4D seismic signals. The idea is to use engineering knowledge to minimize possible incorrect information provided by 4D seismic before using it to update reservoir simulation models in a history matching procedure. In this work the integration between the two dataset is done in the pressure and saturation domain. So, the first part of the work presents a methodology to estimate pressure and saturation changes from 4D seismic through a petro-elastic inversion procedure. This procedure can be seen as a tool to apply the integration methodology of the second part which is one of the main contributions of this work. The integration methodology uses multiple simulation models to constrain the estimation of pressure and saturation from 4D seismic. As a result, less noisy maps were obtained, allowing a better interpretation of the reservoir changes. Following the traditional sequence, the estimated saturation map is then used as input to the history matching process presented in the third part of the work. It was shown that the history matching procedure provides better results if the input data, in this case the saturation map, respects the expected mass balance, which was not the case for the dataset considered. Thus, a methodology to calibrate the volume of injected water associated to the saturation map provided by 4D seismic is presented in the last part of the work, which is another important contribution to be highlighted. To better control the results of all the methodologies here presented, a synthetic dataset was used in the entire work. Although satisfactory results were observed for this dataset, it is important to highlight that the main contributions of this work are not only the results, but the methodologies proposed, that present an innovative perspective for 4D seismic and reservoir engineering data integration
Doutorado
Reservatórios e Gestão
Doutora em Ciências e Engenharia de Petróleo
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Ida, Mauro. "Incorporação quantitativa de dados de sismica 4D no processo de ajuste de historico." [s.n.], 2009. http://repositorio.unicamp.br/jspui/handle/REPOSIP/263736.
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Orientadores: Denis Jose Schiozer, Celio MaschioDissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecanica, Instituto de Geociencias
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Resumo: Boas decisões no gerenciamento de um campo de petróleo em produção dependem fortemente da confiabilidade da previsão de produção que demanda um modelo de escoamento que reproduza com boa precisão o histórico de produção. Devido à complexidade do processo de ajuste de histórico de produção, vários modelos podem resultar em ajustes aceitáveis, porém ainda com incertezas na previsão de produção, principalmente pelo fato de existirem algumas heterogeneidades de grande impacto não observadas na fase de caracterização do modelo. Para reduzir as incertezas, surgiu a tecnologia de sísmica 4D que a partir de análises qualitativas permite identificar frentes de saturação de água, resultando em grandes avanços na caracterização do reservatório e, conseqüentemente, no ajuste de histórico. Apesar de muito útil, em alguns casos podem levar a interpretações equivocadas, sendo necessário um procedimento adicional para o uso da informação dessa tecnologia. O objetivo principal deste trabalho é propor uma metodologia que utiliza simultaneamente os dados de produção e quantitativamente a impedância acústica da sísmica 4D para identificar as heterogeneidades do reservatório visando melhorar a qualidade do ajuste de histórico. A metodologia proposta consiste de duas etapas principais: parametrização e otimização com algoritmo genético. A validação da metodologia proposta foi realizada num modelo bidimensional five-spot com duas falhas geológicas e um canal de alta permeabilidade e a aplicação foi realizada num modelo modificado do Campo de Namorado com as seguintes características: total de 44 poços, uma falha geológica e um canal de alta permeabilidade. Em todos os modelos, foram constatados ganhos de qualidade no ajuste de histórico proporcionado pela incorporação quantitativa da sísmica 4D.
Abstract: Good decision making related to oilfield management depends on reliability of production forecast which demands calibrated reservoir simulation models. Due to the complexity of the production history matching process, there are many models with reasonable match but, many times, with different forecasts, mainly due to important heterogeneities that are not observed during the reservoir characterization phase. In order to reduce this uncertainty, a new technology named 4D seismic became available which uses quantitative analysis to identify water saturation front resulting in huge advance in reservoir characterization and consequently in history matching. Although this technology is very useful, in some cases, it can result in mistaken interpretation and it needs additional work to use this technology. The main objective of this work is to propose a methodology to use production data and quantitatively acoustic impedance from 4D seismic to identify reservoir heterogeneities to increase the quality of the history matching. The methodology proposed is divided in two main steps: parametrization and optimization with genetic algorithm. The validation of methodology proposed was done in a simple synthetic model and the application was done in the Namorado Field, modified with one geological fault and one channel with high permeability.
Mestrado
Reservatórios e Gestão
Mestre em Ciências e Engenharia de Petróleo
26
Avansi, Guilherme Daniel 1984. "Ajuste de histórico integrado à caracterização de reservatórios de petróleo e sísmica 4D." [s.n.], 2014. http://repositorio.unicamp.br/jspui/handle/REPOSIP/265877.
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Orientador: Denis Jose SchiozerTese (doutorado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica, Instituto de Geociências
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Resumo: A simulação numérica é fundamental para a engenharia de reservatórios, possibilitando a previsão de produção e avaliação de modelos em diferentes estágios da vida produtiva de um campo. Todavia, para isso, é necessário calibrar os modelos com dados de histórico de produção e mapas, sendo indispensável um modelo geológico confiável para gerar modelos numéricos consistentes. O processo de ajuste de histórico tem sido integrado às áreas de estudo de caracterização de reservatórios e sísmica 4D para que melhores resultados possam ser obtidos. Muitas vezes, é difícil testar a aplicabilidade de novas metodologias nessas áreas de trabalho, pois os reservatórios reais são desconhecidos no momento das decisões, e raramente são feitos estudos posteriores para isso. Dessa forma, um dos objetivos principais desta tese é a criação de um modelo sintético (UNISIM-I-R), com características reais e resposta conhecida, a partir de dados públicos do Campo de Namorado, Bacia de Campos, Brasil, de forma que o reservatório real possa ser substituído por um modelo de referência para que metodologias sejam testadas e comparadas durante as fases de pré e pós-desenvolvimento do campo. Para testar as aplicações, outros dois modelos são criados, UNISIM-I-D e UNISIM-I-H, para que metodologias de estratégia de produção e de ajuste de histórico sejam testadas, validadas e comparadas. A aplicação utilizada e apresentada neste trabalho é a de ajuste de histórico, integrada à caracterização geológica e sísmica 4D. Mostra-se o ajuste simultâneo de diferentes funções-objetivo, mantendo a consistência dos modelos gerados, de modo a resultar em previsões de produção confiáveis. Para que modelos geológicos sejam calibrados durante a fase de caracterização integrada ao ajuste, perturba-se o modelo geológico utilizando poços virtuais. Sendo assim, as principais contribuições deste trabalho são a construção de um problema típico da engenharia de reservatórios, com resposta conhecida, e de uma metodologia de ajuste de histórico integrada com a caracterização de reservatórios e sísmica 4D, a qual preserva a consistência geológica dos modelos gerados
Abstract: Numerical simulation is essential for reservoir engineering, allowing the production forecasting and models evaluation in different stages of field production. Besides quantifying reservoir uncertainties in a field planning and developing, it is necessary to adjust models with history production and map data, being indispensable a reliable geological model to get consistent numerical ones. History matching process has been integrated to reservoir characterization and 4D seismic study areas in order to get better results. The applicability of new technologies in these areas is frequently restricted to real reservoir applications, once they are unknown at the time of the decision making, and further studies are rarely made for this. This work aims the creation of a synthetic model, UNISIM-I-R, using a public dataset from Namorado Field, Campos Basin, Brazil, where the real reservoir is replaced with a reference model with known properties, so that methodologies can be tested and compared in a pre and post-development stages of field production. In order to test the applications, two other models are built, UNISIM-I-D and UNISIM-I-H, testing, comparing and validating selection of production strategy and history matching approaches. The proposed and used application is the history matching, reservoir characterization and 4D seismic integrated studies. This way, a simultaneous calibration of different objective-function is proposed, keeping the geological consistency in an adjustment approach for a reliable forecast production. However, it is necessary to perturb the geological model using virtual wells during the reservoir characterization to get the calibration. In conclusion, the main contributions of the presented work are the construction of a typical reservoir engineering problem, with known answer, and the development of an integrated history matching by reservoir characterization and 4D seismic, which preserves the consistency of geological models construction
Doutorado
Reservatórios e Gestão
Doutor em Ciências e Engenharia de Petróleo
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Côrte, Gustavo Araújo 1987. "Modelagem e interpretação de sísmica 4D em modelos de simulação numérica de reservatórios : o exemplo do campo de Namorado." [s.n.], 2014. http://repositorio.unicamp.br/jspui/handle/REPOSIP/265855.
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Orientador: Emilson Pereira LeiteDissertação (mestrado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica, Instituto de Geociências
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Resumo: Utilizando uma abordagem integrada de simulação de reservatórios, física de rochas e modelagem sísmica, o presente estudo analisa a influência das mudanças em pressão e distribuição de fluidos em um reservatório em seções sísmicas time-lapse. As formas e ocasiões nas quais essas mudanças podem ser detectadas são estudadas, para auxiliar na caracterização da dinâmica dos fluidos dentro do reservatório. Para analisar esses efeitos, foram conduzidas simulações de fluxo de reservatório em um modelo geológico do reservatório arenítico de Namorado, na bacia de Campos, Brasil. Através de uma abordagem de substituição de fluidos de Gassmann, volumes 4D de impedância no reservatório foram criados a partir dos resultados de simulação. Em seguida, volumes time-lapse de sísmica sintética são analisados. Diferentes situações de injeção de água e de gás foram simuladas, com o intuito de quantificar as diferenças entre as substituições óleo-água e óleo-gás e investigar as diferentes formas que estas afetam as amplitudes sísmicas. As interpretações feitas permitem definir padrões para diferenciar áreas de subtituição de óleo por água e gás, podendo ser útil em casos de injeção alternada de água e gás (WAG)
Abstract: Using an integrated approach of reservoir simulation, rock physics and seismic modelling, the present study analyses the influence of changes in pressure and distribution of fluids in a reservoir on time-lapse seismic sections. The forms and occasions in which these changes can be detected are studied to help in the characterization of the fluid dynamics inside the reservoir. To analyze these effects, reservoir production simulations were conducted in a geological model of the Namorado sandstone reservoir, in Brazil's Campos basin. Through a Gassmann fluid substitution approach, 4D impedance volumes were created from the simulation results and Synthetic time-lapse seismic sections were computed. Simulations of both water injecting and gas injecting situations were conducted in order to quantify the differences between oil-water and oil-gas substitutions and investigate the different ways they affect seismic amplitudes. The interpretations allow the definition of patterns to distinguish areas of substitution of oil by water and gas, which would be useful in water alternating gas (WAG) injection cases
Mestrado
Reservatórios e Gestão
Mestre em Ciências
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Ferreira, Carla Janaina 1984. "Methodology to estimate the chance of success of a 4D seismic project from the reservoir engineering perspective = Metodologia para a estimativa da chance de sucesso de um projeto de sísmica 4D do ponto de vista da engenharia de reservatórios." [s.n.], 2014. http://repositorio.unicamp.br/jspui/handle/REPOSIP/265881.
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Orientador: Denis José SchiozerTese (doutorado) - Universidade Estadual de Campinas, Faculdade de Engenharia Mecânica e Instituto de Geociências
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Resumo: A produção de hidrocarbonetos é um negócio que envolve muitos riscos. As incertezas inerentes à produção estão relacionadas às incertezas no estado físico do reservatório e variáveis externas. A incerteza do reservatório pode ser reduzida conforme dados de produção e dinâmicos são adquiridos. A sísmica 4D (S4D) tem sido utilizada na indústria de petróleo, pois a integração de informação geofísica e de engenharia aumenta a capacidade preditiva da simulação de reservatórios. Entretanto, há questões técnicas que devem ser avaliadas antes de se iniciar um projeto de S4D. Vários estudos geofísicos usam o conceito de chance de sucesso para identificar os casos favoráveis onde são avaliados o levantamento sísmico e a magnitude das mudanças sísmicas. Porém, do ponto de vista de engenharia é importante avaliar o impacto da nova informação na operação do campo e o consequente benefício financeiro. A estimativa da chance de sucesso de um projeto de S4D é um desafio. Portanto, este trabalho apresenta uma metodologia que estima a chance de sucesso sob a perspectiva da engenharia de reservatórios. A metodologia foi desenvolvida em três fases. A primeira fase mostra que o erro de saturação de água pode ser utilizado para medir a melhora no entendimento da movimentação de fluidos no reservatório devido à aquisição da S4D. Além disso, mostra que o momento em que a sísmica 4D é adquirida impacta no valor da informação. Na segunda fase a metodologia para determinar o melhor momento para a aquisição da S4D é apresentada. O melhor momento é determinado avaliando o tempo para a chegada de água nos poços e as curvas de erro de saturação. Por fim, a metodologia para a estimativa da chance de sucesso é apresentada. A metodologia é um processo iterativo simples. A metodologia é composta por seis etapas, no qual algumas são bem estabelecidas na literatura. A tese incorpora a data que aquisição da sísmica 4D no processo e avalia a chance de sucesso por meio da variação do beneficio econômico ocasionado pelas incertezas do reservatório. A metodologia foi aplicada para um caso sintético para ilustrar o procedimento do cálculo do valor da informação e da probabilidade de sucesso
Abstract: Production of hydrocarbons is a high-risk business. The uncertainties inherent to production are related to the uncertainties in the physical state of the reservoir and external variables. Reservoir uncertainty can be reduced as new production and dynamic data become available. 4D seismic technology has been used in the petroleum industry because the integration of geophysics and engineering information increases the predictive capability of reservoir simulations. However, there are technical issues to be addressed before starting a 4D seismic project. Several geophysical studies use the chance of success concept to identify the favorable cases; evaluating the seismic survey and the magnitude of seismic changes. From the engineering point of view, it is important to evaluate the impact of new information on field operations and the consequent monetary benefit. The estimation of 4D seismic data chance of success before its acquisition is a challenge. Therefore, the thesis presents a methodology to estimate the chance of success of a 4D seismic project from the reservoir engineering perspective. The methodology was developed in three phases. The first phase shows that water saturation error can measure the improvement on the fluid behavior understanding due to 4D seismic data. Moreover, it shows that the time for 4D seismic data acquisition affects its value. The second phase presents the methodology to estimate the best time to acquire 4D seismic data. The best time estimation is determined by evaluating time for water breakthrough and the water saturation error curves. Finally, the chance of success methodology is presented. The methodology is simple and an iterative process. It is divided in six steps, in which some of them are well established in the literature. The thesis incorporates the date of 4D seismic data acquisition in the process and assesses the chance of success through the variation in the economic benefit caused by the reservoir uncertainties. The methodology was applied to a synthetic reservoir model, showing a procedure to estimate the expected value of information and the probability of success
Doutorado
Reservatórios e Gestão
Doutora em Ciências e Engenharia de Petróleo
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Borges, De Salles Abreu Carlos Eduardo Royer Jean-Jacques. "Time-lapse (4D) seismic interpretation methodologies based on kriging analysis application to the Senlac (onshoreCanada) and Marlim ( offshore Brazil) heavy oilfields /." S. l. : INPL, 2008. http://www.scd.inpl-nancy.fr/theses/2008_BORGES_DE_SALLES_ABREU_C_E.pdf.
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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.
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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.
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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.
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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.
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Alfataierge, Ahmed. "3D Modeling and Characterization of Hydraulic Fracture Efficiency Integrated with 4D/9C Time-Lapse Seismic Interpretations in the Niobrara Formation, Wattenberg Field, Denver Basin." Thesis, Colorado School of Mines, 2018. http://pqdtopen.proquest.com/#viewpdf?dispub=10634132.
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Hydrocarbon recovery rates within the Niobrara Shale are estimated as low as 2–8%. These recovery rates are controlled by the ability to effectively hydraulic fracture stimulate the reservoir using multistage horizontal wells. Subsequent to any mechanical issues that affect production from lateral wells, the variability in production performance and reserve recovery along multistage lateral shale wells is controlled by the reservoir heterogeneity and its consequent effect on hydraulic fracture stimulation efficiency. Using identical stimulation designs on a number of wells that are as close as 600ft apart can yield variable production and recovery rates due to inefficiencies in hydraulic fracture stimulation that result from the variability in elastic rock properties and in-situ stress conditions.
As a means for examining the effect of the geological heterogeneity on hydraulic fracturing and production within the Niobrara Formation, a 3D geomechanical model is derived using geostatistical methods and volumetric calculations as an input to hydraulic fracture stimulation. The 3D geomechanical model incorporates the faults, lithological facies changes and lateral variation in reservoir properties and elastic rock properties that best represent the static reservoir conditions pre-hydraulic fracturing. Using a 3D numerical reservoir simulator, a hydraulic fracture predictive model is generated and calibrated to field diagnostic measurements (DFIT) and observations (microseismic and 4D/9C multicomponent time-lapse seismic). By incorporating the geological heterogeneity into the 3D hydraulic fracture simulation, a more representative response is generated that demonstrate the variability in hydraulic fracturing efficiency along the lateral wells that will inevitability influence production performance.
Based on the 3D hydraulic fracture simulation results, integrated with microseismic observations and 4D/9C time-lapse seismic analysis (post-hydraulic fracturing & post production), the variability in production performance within the Niobrara Shale wells is shown to significantly be affected by the lateral variability in reservoir quality, well and stage positioning relative to the target interval, and the relative completion efficiency. The variation in reservoir properties, faults, rock strength parameters, and in-situ stress conditions are shown to influence and control the hydraulic fracturing geometry and stimulation efficiency resulting in complex and isolated induced fracture geometries to form within the reservoir. This consequently impacts the effective drainage areas, production performance and recovery rates from inefficiently stimulated horizontal wells.
The 3D simulation results coupled with the 4D seismic interpretations illustrate that there is still room for improvement to be made in optimizing well spacing and hydraulic fracturing efficiency within the Niobrara Formation. Integrated analysis show that the Niobrara reservoir is not uniformly stimulated. The vertical and lateral variability in rock properties control the hydraulic fracturing efficiency and geometry. Better production is also correlated to higher fracture conductivity. 4D seismic interpretation is also shown to be essential for the validation and calibration hydraulic fracture simulation models. The hydraulic fracture modeling also demonstrations that there is bypassed pay in the Niobrara B chalk resulting from initial Niobrara C chalk stimulation treatments. Forward modeling also shows that low pressure intervals within the Niobrara reservoir influence hydraulic fracturing and infill drilling during field development.
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Herrmann, Felix J. "Curvelet imaging and processing : an overview." Canadian Society of Exploration Geophysicists, 2004. http://hdl.handle.net/2429/506.
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In this paper an overview is given on the application of directional basis functions, known under the name Curvelets/Contourlets, to various aspects of seismic processing and imaging. Key concepts in the approach are the use of (i) that localize in both domains (e.g. space and angle); (ii) non-linear estimation, which corresponds to localized muting on the coefficients, possibly supplemented by constrained optimization (iii) invariance of the basis functions under the imaging operators. We will discuss applications that include multiple and ground roll removal; sparseness-constrained least-squares migration and the computation of 4-D difference cubes.
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Gautre, Christy. "Time-Lapse Depletion Modeling Sensitivity Study: Gas-Filled Gulf of Mexico Reservoir." ScholarWorks@UNO, 2010. http://scholarworks.uno.edu/td/1187.
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Time-lapse seismic allows oil/gas reservoir monitoring during production, highlighting compaction and water movement. Time-lapse modeling, using a stress-dependent rock physics model, helps determine the need and frequency of expensive repeat seismic acquisition. We simulate a Gulf of Mexico gas reservoir time-lapse response for depletion and water flooding using uncertainty ranges in water saturation, porosity, stress-induced velocity changes, and pore compressibility. An analysis is conducted to see if a water-swept region could have been predicted. Findings show the swept and un-swept monitor cases amplitude differences range from 6% to 15%, which is higher than the actual monitor seismic noise level. Thus, it is unlikely these cases could be differentiated. However, the modeled amplitude changes from base to monitor cases do not match measured amplitude changes. This suggests the rock property model requires pressure-variance improvement and/or the changes in seismic amplitudes are associated with pressure/porosity, thickness, or saturation cases not modeled.
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Mastio, Nicolas. "Improving the global coherency of the Shared Earth Model using static, dynamic and geomechanics data." Electronic Thesis or Diss., Université de Lorraine, 2020. http://www.theses.fr/2020LORR0258.
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La production des réservoirs pétrolifères modifie l'état de contrainte du sous-sol. L'extraction du pétrole induit une diminution de la pression des pores et la roche réservoir est soumise à un chargement supplémentaire. Le réservoir n'est la seule région affectée par la production : les couches sus-jacentes et sous-jacentes se déplacent aussi. Pour comprendre l'effet de la compaction du réservoir sur les couches sus-jacentes et sur la subsidence, des modèles géomécaniques sont construits. Le comportement élastique et le changement de la pression des pores sont utilisés pour calculer le champ de déplacement et le changement d'état de contrainte. Néanmoins, les modèles des champs pétrolifères sont entachés d'incertitudes parce que les données sont éparses, mal-comprises et elles sont le résultat d'un traitement long et complexe. L'incertitude des données rends leur interprétation et leur utilisation difficile. Pour améliorer la prédictibilité des modèles, les données sismiques comme la sismique 4D sont utilisés dans le processus de construction du modèle géomécanique. La sismique 4D est empreinte par l'écoulement des fluides dans le réservoir, par sa déformation et celle des roches environnantes et par l'endommagement des roches. Dans la plupart des champs en production, la quantité de « time-shifts » (la différence en temps de trajet des réflecteurs) dans les roches sus-jacentes est importante. Ce signal s'explique en partie par la déformation, mais surtout par le changement de la vitesse des ondes sismiques. L'ouverture de petites fractures peut induire des changements de vitesse fort. Les modèles de fractures permettent d'expliquer ce changement de propriétés élastique durant un changement d'état de contraintes. Grâces à des modèles synthétiques, des auteurs ont prédits que le changement de vitesses est anisotrope parce que le changement d'état de contrainte dans les roches sus-jacentes est anisotrope. Cependant, l'anisotropie du changement de vitesse en sismique 4D n'est pas considérée. L'inversion 4D ne considère que des changements de vitesse verticale. L'objet de cette thèse est d'extraire plus d'information dans les données pour créer une description plus précise du sous-sol. En utilisant des méthodes d'ensemble, le modèle géomécanique est mis-à-jour en utilisant des données issues de l'inversion sismique 4D. Pour ce faire, nous proposons en premier lieu d'obtenir la variation de pression du réservoir qui permet d'expliquer des données sismiques 4D. Cette étude suggère que la compartimentalisation du réservoir doit être réévaluée afin de comprendre les données sismiques. Puis, nous proposons d'obtenir l'anisotropie du changement de vitesse à partir des données sismiques 4D avant sommation. Une reconstruction tomographique de ce changement de vitesse permet de réaligner la base au monitor. Cette méthode est appliquée sur un cas d'étude réel. L'anisotropie du champ de vitesse obtenue corresponds à une diminution d'epsilon et de delta en termes de paramètres de Thomsen alors que le changement de vitesse verticale est faible. Les modèles géomécaniques montrent que la déformation des roches sus-jacentes est compatible avec l'ouverture de fractures horizontales ; ce n'est pas ce que l'on observe dans notre cas d'étude. Pour expliquer nos résultats, nous proposons un modèle de roches dans lequel se développe une fracturation verticale dans une roche saturée en eau. Ces fractures ont un rapport d'aspect faible (entre 10-2 et 10-3). Cette seconde approche nous interroge sur les hypothèses faites quand les prédictions des modèles géomécaniques sont comparées aux résultats d'inversion 4D. Ces deux approches montrent un grand potentiel dans l'amélioration de la cohérence et la réduction des incertitudes dans les modèles quand différentes données sont confrontées. Davantage d'effort est nécessaire afin de construire un modèle du sous-sol qui permettrait de comprendre toutes les données à notre dispositionPetroleum reservoir production modifies the stress state of the subsurface. Petroleum is drawn out, the reservoir pore pressure decreases, and the reservoir rock supports an additional loading. The reservoir is not the only affected area of the field during the production: the layers above (the overburden) and below (the underburden) move. To understand the effect of the reservoir compaction on the overburden and on the subsidence, geomechanical models are built. The rock elastic behavior and the pore pressure change are used to compute the displacement field and the stress changes. In any case, the models of petroleum fields are riddled with uncertainties because the data are sparse and fuzzy and often the results of a long and complex processing. The data uncertainties make the interpretation difficult, or the usage of the prediction made by reservoir models. To reduce these uncertainties, seismic data such as time-lapse seismic (4D) is used in the geomechanical modelling workflow. 4D seismic are imprinted by the fluid flow in the reservoir, by the strain in the reservoir and in the overburden, and by the rock damaging. In most of the produced fields, the amount of time shifts (the reflectors time-arrival difference) in the overburden is significant. While only a small part of the overburden time shifts is explained by the strain, the velocity change plays a major role. But the relationship between the velocity change and the stress state change due to the reservoir compaction is not known. Microcracks opening is known to have a strong effect on the velocity change. Crack-based models can explain the stress-dependent velocity change in rock samples. Based on synthetics models, different authors predict that the velocity change is anisotropic because the stress change in the overburden is anisotropic. However, the velocity change anisotropy is not considered in the classic time-lapse seismic inversion as only the vertical direction is considered. The object of this thesis is to extract more information from the data to create a more precise description of the subsurface model. A Mechanical History Matching of time-lapse inverted time strains using Ensemble methods is performed. For this, we first propose to invert for pressure variation in the reservoir to match the time-lapse seismic data. Using the empirical R-factor law, time-lapse time strains are predicted by the mechanical vertical strains. The reservoir pore pressure is updated to match the geomechanical model predictions with the time-lapse inversion results, suggesting that a new compartmentalization of the reservoir is needed to match the 4D information in the overburden. This first approach interrogates on the usage of reservoir simulation data in the geomechanical model. Second, we propose to recover the velocity change anisotropy from prestack time-lapse seismic data. A tomographic reconstruction of the velocity change is performed by realigning the baseline to the monitor. The method is applied to a real case study. The retrieved anisotropic velocity change in the overburden corresponds to a large decrease in epsilon and delta in terms of Thomsen parameters while the vertical velocity change is tiny. Classically, geomechanical models show an overburden stretching corresponding to an opening of horizontal cracks; this is not what we observe in the velocity change anisotropy. To explain the data, we propose a rock-physics model corresponding to vertical cracks with a small aspect ratio (between 10-2 and 10-3) in a water-saturated rock. This second approach interrogates on the assumptions made when the geomechanical model simulation results are compared to the time-lapse seismic inversion results. As shown in the two approaches, a great potential for improving the consistency and reduce uncertainty of the models exists when mixing various data. This work is preliminary and much more work is required to integrate all sources of data into the shared earth model
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Brito, Eduardo Eudes Farias de. "An?lise da trajet?ria de po?os horizontais em reservat?rio de ?leo pesado." Universidade Federal do Rio Grande do Norte, 2008. http://repositorio.ufrn.br:8080/jspui/handle/123456789/12932.
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Previous issue date: 2008-12-01The application of thermal methods, to increase the recovery of heavy oil in mature fields through drainage with multilateral and horizontal wells, has been thoroughly studied, theorically, experimentally, testing new tools and methods. The continuous injection of steam, through a steam injector well and a horizontal producer well in order to improve horizontal sweep of the fluid reservoir, it is an efficient method. Starting from an heterogeneous model, geologically characterized, modeling geostatistics, set history and identification of the best path of permeability, with seismic 3D, has been dubbed a studying model. It was studied horizontal wells in various directions in relation to the steam and the channel of higher permeability, in eight different depths. Into in the same area were studied, the sensitivity of the trajectories of horizontal wells, according to the depth of navigation. With the purpose of obtaining the highest output of oil to a particular flow, quality, temperature and time for the injection of steam. The wells studied showed a significant improvement in the cumulative oil recovery in one of the paths by promoting an alternative to application in mature fields or under development fields with heavy oil
A aplica??o de m?todos t?rmicos, para aumentar a recupera??o de ?leo pesado em campos maduros atrav?s da drenagem com po?os horizontais e multilaterais, tem sido exaustivamente estudada, te?rica e experimentalmente, testando novas ferramentas e novos m?todos. A inje??o cont?nua de vapor, atrav?s de um po?o injetor e de um po?o horizontal produtor com o objetivo de proporcionar uma varredura dos fluidos do reservat?rio, mostra-se um m?todo eficiente. Partindo de um modelo heterog?neo, geologicamente caracterizado por, modelagem geoestat?stica, ajuste de hist?rico e identifica??o do melhor caminho de permeabilidade, com a s?smica 3D, foi montado um modelo para estudo. Foram estudados po?os horizontais em v?rias dire??es em rela??o ao injetor de vapor e ao canal de maior permeabilidade, em oito profundidades diferentes. Dentro de uma mesma zona foram estudadas, a sensibilidade das trajet?rias de po?os horizontais, em fun??o da profundidade de navega??o. Com a finalidade de obter a maior produ??o acumulada de ?leo a uma determinada vaz?o, qualidade, temperatura e per?odo de inje??o do vapor. Os po?os estudados evidenciam uma melhora significativa na recupera??o acumulada de ?leo em uma das trajet?rias, promovendo uma alternativa de aplica??o em campos maduros ou em desenvolvimento com ?leo pesado
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García, Juanatey María de los Ángeles. "Seismics, 2D and 3D Inversion of Magnetotellurics : Jigsaw pieces in understanding the Skellefte Ore District." Doctoral thesis, Uppsala universitet, Geofysik, 2012. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-178060.
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The Skellefte District (SD) is one of the richest metallogenic mining areas in Sweden. The main deposits consist of volcanic-hosted massive sulphides (VHMS) rich in zinc, copper, lead, gold and silver, that have been explored and mined for more than a century. Considering that technological advancements allow deeper mining, and that today new discoveries rarely occur, renewed efforts are now directed at locating targets at greater depths. Thus, current exploration strategies need to be adapted, and a better understanding of regional scale structures is necessary. To address these questions the project VINNOVA 4D modeling of the Skellefte District was launched. Its main purpose is to unravel the regional structures and tectonic setting of the SD. To accomplish this, new geological and geophysical data have been acquired in two key localities. This thesis presents the contribution from 2D and 3D inversion of magnetotelluric (MT) data and seismic reflection data. The main findings include: conductive hydrothermally altered zones within the otherwise resistive rocks of the Skellefte Group, the depth extension of early and postorogenic intrusions, prominent shear zones in the central part of the district, and enhanced reflectivity and conductivity at the base of the Skellefte Group throughout the SD. Even though the application of these methods is challenged by the complex geological setting of the SD, it is shown that after a careful processing and analysis of the data, they are able to provide a robust image of the deep subsurface. Additionally, the combination of reflection seismics and MT has proved to be a powerful tool for hypothesis testing and to develop the general understanding of the configuration and history of the SD. Furthermore, two 3D inversion models of MT data are presented and compared with the results of standard 2D determinant inversions. The 3D procedure shows significant improvements in data fit and is able to constrain better the observed model features. Although 3D inversion of MT data is not yet a run of the mill scheme and issues like model assessment and galvanic distortion effects need to be further addressed, results from complex environments with areal coverage, are already superior to those from 2D inversions.Skellefteåfälten är ett av de viktigaste malmdistrikten i Sverige. Malmkropparna består av vulkaniskvärda Massiva Sulfider (VHMS) rika på Zink, Koppar, Bly, Guld och Silver, och har utforskats och brutits i mer än ett sekel. Med tanke på att de senaste tekniska framstegen tillåter djupare brytning, och att nya upptäckter är ovanliga idag, riktas nya ansträngningar mot att lokalisera malm på större djup. Aktuella prospekteringsstrategier måste därför anpassas, och en bättre förståelse av regionala strukturer är nödvändig. För att lösa dessa frågor lanserades projektet VINNOVA 4D modeling of the Skellefte District. Dess främsta syfte är att utreda de regionala strukturerna och det tektoniska läget av Skelleftefältet. För att uppnå detta, har nya geologiska och geofysiska data insamlats vid två viktiga platser i distriktet. Denna avhandling presenterar bidrag från inversionsmodellering i 2D och 3D av magnetotelluriska (MT) data samt resultaten av en reflektionsseismisk profil. De viktigaste resultaten är: bra ledande hydrotermiskt förändrade zoner inom de annars resistiva bergarterna i Skellefte-gruppen, djupet till tidiga och postorogeniska intrusioner, framstående skjuvzoner i den centrala delen av området, och ökad reflektionsförmåga och konduktivitet vid basen av Skellefte-gruppen i hela fältet. Även om tillämpningen av dessa metoder utmanas av fältens komplexa geologiska läge, visas det efter en noggrann bearbetning och analys av data att de ger en robust bild av den lite djupare berggrunden. Dessutom har kombinationen av reflektionsseismik och MT visat sig vara ett kraftfullt verktyg för hypotesprövning och för att utveckla den allmänna förståelsen av Skelleftefältet och dess historia. Därutöver presenteras två 3D inversionsmodeller av MT data och jämförs sedan med resultaten från 2D determinantinversioner. 3D tekniker visar betydande förbättringar av datapassform och begränsar observerade anomalier bättre. Även om 3D inversion av MT data ännu inte är en vanlig teknik och frågor som modellbedömning och galvaniska distorsionseffekter måste behandlas ytterligare, är resultat från komplexa miljöer med lagom yttäckning redan överlägsna.
VINNOVA 4D modeling of the Skellefte District
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Sinha, Mrinal. "Interferometric Imaging and its Application to 4D Imaging." Diss., 2018. http://hdl.handle.net/10754/627679.
Full textAbstract:
This thesis describes new interferometric imaging methods for migration and waveform
inversion. The key idea is to use reflection events from a known reference reflector
to ”naturally redatum” the receivers and sources to the reference reflector.
Here, ”natural redatuming” is a data-driven process where the redatuming Green’s
functions are obtained from the data. Interferometric imaging eliminates the statics
associated with the noisy overburden above the reference reflector.
To mitigate the defocussing caused by overburden errors I first propose the use
of interferometric least-squares migration (ILSM) to estimate the migration image.
Here, a known reflector is used as the reference interface for ILSM, and the data
are naturally redatumed to this reference interface before imaging. Numerical results
on synthetic and field data show that ILSM can significantly reduce the defocussing
artifacts in the migration image.
Next, I develop a waveform tomography approach for inverting the velocity model
by mitigating the velocity errors in the overburden. Unresolved velocity errors in the
overburden velocity model can cause conventional full-waveform inversion to get stuck
in a local minimum. To resolve this problem, I present interferometric full-waveform
inversion (IFWI), where conventional waveform tomography is reformulated so a velocity
model is found that minimizes the objective function with an interferometric
crosscorrelogram misfit. Numerical examples show that IFWI, compared to FWI,
computes a significantly more accurate velocity model in the presence of a nearsurface
with unknown velocity anomalies.
I use IFWI and ILSM for 4D imaging where seismic data are recorded at different
times over the same reservoir. To eliminate the time-varying effects of the near
surface both data sets are virtually redatumed to a common reference interface before
migration. This largely eliminates the overburden-induced statics errors in both data
sets. Results with synthetic and field data show that ILSM and IFWI can suppress
the artifacts caused by non-repeatability in time-lapse surveys. This can lead to a
much more accurate characterization of the movement of fluids over time. In turn,
this information can be used to optimize the extraction of resources in enhanced oil
recovery (EOR) operations.
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Liao, Jun-Fu, and 廖峻甫. "Using Seismic Data to Explore the 4D Seismogenic Structures." Thesis, 2015. http://ndltd.ncl.edu.tw/handle/s5xqt2.
Full textAbstract:
碩士國立中正大學
地震研究所
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Taiwan is situated in the collision boundary of the Eurasian Plate and the Philippine Sea plate. The Philippine Sea Plate moves in NW direction with convergent rate of 8.2 cm/yr. The ongoing orogenic process causes a series of imbricate fold-thrust belts in the Western Foothill of Taiwan. It leads to complex seismogeneric structures beneath which are not well understood. In central Taiwan, there were several disastrous earthquakes occurred, such as 1904 Douliu earthquake, 1906 Meishan earthquake, 1935 Hsinchu-Taichung earthquake, the great 1999 Chi-Chi (ML=7.3 ; depth=8km), 2013/03/27 (ML=6.2 ; depth=19.4km ) and 2013/06/02 (ML=6.4 ; depth=14.5km ) Nantou earthquake sequence. One of the major objectives of this study is to investigate the evolution of velocity structures before and after the occurrence of the abovementioned earthquakes. The other important goal is to exam the temporal variations of velocity structures including Vp, Vs and Vp/Vs beneath central Taiwan since the occurrence of the Chi-Chi earthquake. Our study area is from 120.0o E to 122.0o E in longitude, while the latitude is between 23.5o N and 24.5o N. We have used the travel time data compiled by the Central Weather Bureau (CWB) from 1991 to 2014 to build a 3D velocity map from the crustal area to the uppermost mantle. We also divided the whole study time span into 6 segments to investigate velocity structures in different time periods. The software package called LOTOS is applied to perform tomographic inversion. The main advantage of the method is to allow the travel times of deeper earthquakes occurred outside study area in the inversion process to improve the resolution of the velocity structure at deeper depths. The results show that the temporal variation of Vp is less significant than Vs, and Vp does not show prominent perturbation before and after the occurrence of a large earthquake. However, Vs and Vp / Vs in the source area demonstrate significant temporal and spatial difference before and after major shocks. In general, before the strike of an earthquake in central Taiwan, Vs begins to decreased (Vp/Vs is increased) in focal area, which may caused by the increasing of microcracks produced by accumulated stress. But in the vicinity of source area, Vs is increasing which may be due to closing of cracks. Our findings suggest that the monitoring Vs and Vp/Vs structures may used as an earthquake precursor to reduce seismic hazard in central Taiwan.
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Ravanelli, Fabio M. "History Matching of 4D Seismic Data Attributes using the Ensemble Kalman Filter." Thesis, 2013. http://hdl.handle.net/10754/294183.
Full textAbstract:
One of the most challenging tasks in the oil industry is the production of reliable reservoir forecast models. Because of different sources of uncertainties the numerical models employed are often only crude approximations of the reality. This problem is tackled by the conditioning of the model with production data through data assimilation. This process is known in the oil industry as history matching. Several recent advances are being used to improve history matching reliability, notably the use of time-lapse seismic data and automated history matching software tools. One of the most promising data assimilation techniques employed in the oil industry is the ensemble Kalman filter (EnKF) because its ability to deal with highly non-linear models, low computational cost and easy computational implementation when compared with other methods.
A synthetic reservoir model was used in a history matching study designed to predict the peak production allowing decision makers to properly plan field development actions. If only production data is assimilated, a total of 12 years of historical data is required to properly characterize the production uncertainty and consequently the correct moment to take actions and decommission the field. However if time-lapse seismic data is available this conclusion can be reached 4 years in advance due to the additional fluid displacement information obtained with the seismic data. Production data provides geographically sparse data in contrast with seismic data which are sparse in time.
Several types of seismic attributes were tested in this study. Poisson’s ratio proved to be the most sensitive attribute to fluid displacement. In practical applications, however the use of this attribute is usually avoided due to poor quality of the data. Seismic impedance tends to be more reliable.
Finally, a new conceptual idea was proposed to obtain time-lapse information for a history matching study. The use of crosswell time-lapse seismic tomography to map velocities in the interwell region was demonstrated as a potential tool to ensure survey reproducibility and low acquisition cost when compared with full scale surface surveys. This approach relies on the higher velocity sensitivity to fluid displacement at higher frequencies. The velocity effects were modeled using the Biot velocity model. This method provided promising results leading to similar RRMS error reductions when compared with conventional history matched surface seismic data.
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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
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Ditkof, Julie Nicole. "Time-lapse seismic monitoring for enhanced oil recovery and carbon capture and storage field site at Cranfield field, Mississippi." 2013. http://hdl.handle.net/2152/23200.
Full textAbstract:
The Cranfield field, located in southwest Mississippi, is an enhanced oil recovery and carbon sequestration project that has been under a continuous supercritical CO₂ injection by Denbury Onshore LLC since 2008. Two 3D seismic surveys were collected in 2007, pre-CO₂ injection, and in 2010 after > 2 million tons of CO₂ was injected into the subsurface. The goal of this study is to characterize a time-lapse response between two seismic surveys to understand where injected CO₂ is migrating and to map the injected CO₂ plume edge. In order to characterize a time-lapse response, the seismic surveys were cross equalized using a trace-by-trace time shift. A normalized root-mean-square (NRMS) difference value was then calculated to determine the repeatability of the data. The data were considered to have “good repeatability,” so a difference volume was calculated and showed a coherent seismic amplitude anomaly located through the area of interest. A coherent seismic amplitude anomaly was also present below the area of interest, so a time delay analysis was performed and calculated a significant added velocity change. A Gassmann-Wood fluid substitution workflow was then performed at two well locations to predict a saturation profile and observe post-injection expected changes in compressional velocity values at variable CO₂ saturations. Finally, acoustic impedance inversions were performed on the two seismic surveys and an acoustic impedance difference volume was calculated to compare with the fluid substitution results. The Gassmann-Wood fluid substitution results predicted smaller changes in acoustic impedance than those observed from acoustic impedance inversions. At the Cranfield field, time-lapse seismic analysis was successful in mapping and quantifying the acoustic impedance change for some seismic amplitude anomalies associated with injected CO₂. Additional well log data and refinement of the fluid substitution workflow and the model-based inversion performed is necessary to obtain more accurate impedance changes throughout the field instead of at a single well location.text
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Rey, Amaya Alvaro. "Fast History Matching of Time-Lapse Seismic and Production-Data for High Resolution Models." Thesis, 2011. http://hdl.handle.net/1969.1/ETD-TAMU-2011-08-9691.
Full textAbstract:
Seismic data have been established as a valuable source of information for the construction of reservoir simulation models, most commonly for determination of the modeled geologic structure, and also for population of static petrophysical properties (e.g. porosity, permeability). More recently, the availability of repeated seismic surveys over the time scale of years (i.e., 4D seismic) has shown promising results for the qualitative determination of changes in fluid phase distributions and pressure required for determination of areas of bypassed oil, swept volumes and pressure maintenance mechanisms. Quantitatively, and currently the state of the art in reservoir model characterization, 4D seismic data have proven distinctively useful for the calibration of geologic spatial variability which ultimately contributes to the improvement of reservoir development and management strategies. Among the limited variety of techniques for the integration of dynamic seismic data into reservoir models, streamline-based techniques have been demonstrated as one of the more efficient approaches as a result of their analytical sensitivity formulations. Although streamline techniques have been used in the past to integrate time-lapse seismic attributes, the applications were limited to the simplified modeling scenarios of two-phase fluid flow and invariant streamline geometry throughout the production schedule.
This research builds upon and advances existing approaches to streamline-based seismic data integration for the inclusion of both production and seismic data under varying field conditions. The proposed approach integrates data from reservoirs under active reservoir management and the corresponding simulation models can be constrained using highly detailed or realistic schedules. Fundamentally, a new derivation of seismic sensitivities is proposed that is able to represent a complex reservoir evolution between consecutive seismic surveys. The approach is further extended to manage compositional reservoir simulation with dissolution effects and gravity-convective-driven flows which, in particular, are typical of CO2 transport behavior following injection into deep saline aquifers. As a final component of this research, the benefits of dynamic data integration on the determination of swept and drained volumes by injection and production, respectively, are investigated. Several synthetic and field reservoir modeling scenarios are used for an extensive demonstration of the efficacy and practical feasibility of the proposed developments.