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73rd EAGE Conference and Exhibition incorporating SPE EUROPEC 2011
- Conference date: 23 May 2011 - 27 May 2011
- Location: Vienna, Austria
- ISBN: 978-90-73834-12-5
- Published: 23 May 2011
781 - 799 of 799 results
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Engineering and Geophysical Approach for Site Selection at Al-Amal Area, Southeast of Cairo, Egypt
More LessGenerally, near surface geophysical techniques like the high resolution microgravity approved its applicability for detecting the near-surface caves. This paper is aimed at demonstrating the link between geophysical and engineering parameters of the soil and rocks in one package required by engineers at any site before starting constructions. Microgravity measurements were acquired in the Al-Amal area southeast of Cairo, Egypt as a case study in order to detect the near-surface caves. The survey showed there are indications of voids/caves in the uppermost subsurface layer formed by the Eocene limestone. At the same time, rock samples were collected from an exposed section through a small valley in the study area. The samples were subjected for soil tests to study various mechanical and petrophysical properties. The grain size analysis revealed coarse grained classification of the soil. The other geomechanical and petrophysical analyses provided detailed rock and soil characterization, such as compressive strength, porosity, bulk density and permeability. In accordance with microgravity, it was found that the first 2 – 3 m represent low strength and low stability formation for big constructions. This layer should be either removed, or the foundations should penetrate to bigger depth.
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Fault or Frac? Source Mechanism and B-value Detection of Fault Fracturing - A Barnett Case Study
Authors A. De La Pena, S. A. Wessels, A. R. Gunnell, K. J. Numa, S. Williams-Stroud, L. Eisner, M. Thornton and M. MuellerMicroseismic monitoring is necessary to optimize hydraulic stimulation in unconventional reservoirs. Recognizing the difference between reactivating pre-existing joints and tectonic faults allows engineers to improve efficiency by avoiding stimulation of faults that may intersect aquifers and do not contribute to hydrocarbon production. Gutenberg and Richter (1954) proposed a relationship of size of events and number of events for a given area to be log N = A -bMs, where the slope b≈1 for tectonic fault earthquakes. Maxwell et al. (2009) and Downie et al. (2010) observed a slope of b≈2 for hydraulically stimulated fracture events. We show that source mechanism inversion of wide azimuth microseismic data acquired with buried array technology can provide this information in real time for each event. We do this on the basis that observed fracture and fault events exhibit unique source mechanisms, allowing us to calculate b values for thousands of events grouped by their source mechanism. The calculated slopes are consistent with previously published works regarding differentiation of fracture and fault activity. This knowledge will allow engineers to make more informed decisions to reduce the volume of fluids and proppants lost to reactivated faults.
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A Novel Hybrid Wireline Logging System for Downhole Monitoring of Fluid Injection and Production in Deep Reservoirs
Authors J. Henninges, G. Baumann, W. Brandt, C. Cunow, M. Poser, J. Schrötter and E. HuengesDuring both geological storage of CO2 and extraction of geothermal heat, fluids are injected in and produced from the subsurface. Classic production logging (PL) includes downhole measurement of pressure, temperature, and fluid velocities, e.g. with a spinner flow meter, to estimate flow rates and phase composition within a flowing well. But during production of geothermal fluids, usually larger flow rates than in standard oil and gas wells are necessary. Physical and chemical properties of CO2 lead to a different flow behavior, as well as possible fluid-rock interactions and corrosion of the borehole completion. The method of fiber-optic distributed temperature sensing (DTS) enables instantaneous registration of continuous temperature profiles over distances of 20 kilometers and longer with high temporal resolution. Here we present the design and first field test of a new hybrid wireline logging system, which combines both classic electric wireline logging tools for PL and depth correlation, as well as optical fibers included in the logging cable for acquisition of DTS temperature profiles. The DTS data was calibrated using the wireline temperature data measured under static conditions. Sufficient temperature resolution for detection of small-scale changes during dynamic flow processes can be achieved.
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Automated RTM-based DIT Scans for Salt Interpretation and Model Building
Reverse Time Migration (RTM) based Delayed Imaging Time (DIT) scans have been used routinely in production to update velocity models in subsalt or low signal to noise areas. Recently, this approach has been enhanced in two areas. Firstly, an automated methodology has been developed that both enhances the quality of the analysis and significantly reduces project turnaround time. Secondly, the automated method is used as an effective tool to help salt velocity model building. In this paper we first describe briefly the automated RTM-based DIT scan methodology; we then show real data examples that demonstrate the effectiveness of DIT scans for better salt model building in complex areas.
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Velocity Prediction and Secondary-pores Quantitative Inversion for Complex Carbonate Reservoir
More LessDissolved caves, holes, and cracks are the main secondary pore types for carbonate reservoirs in Tarim Basin. Velocities of elastic wave propagating in this kind of complex reservoirs change enormously for different secondary pore shapes. Based on Berryman’s differential effective medium (DEM) model and Gassmann’s equation, a rock physics model for complex carbonate reservoirs is established by modeling geometrical shapes of different secondary pores. This model is employed to predict the P- and S-wave velocities of carbonate reservoirs in Tarim Basin. The predicted results are consistent well with the measured data, proving the practicality of the rock physics model on velocity prediction for complex carbonate reservoirs. Additionally, an idea is proposed to quantitatively invert the secondary pores by inversely employing the rock physics model. The feasibility of this idea and the rationality of the inversion results are proven by the consistence between the inverted secondary pore types and those indicated in FMI data.
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Full-Wavefield Inversion of Marine Streamer Data with the Encoded Simultaneous Source Method
Authors P. S. Routh, J. R. Krebs, S. Lazaratos, A. I. Baumstein, I. Chikichev, S. Lee, N. Downey, D. Hinkley and J. E. AndersonRecent developments in simultaneous source techniques for full-wavefield inversion have shown promise in significantly reducing the computational cost. The key is in reducing the large number of individual shots with one or a few encoded shots, thereby providing computational savings for both forward simulation and gradient computation. However, the majority of the applications of this approach have focused on a fixed-receiver geometry, where each receiver records all shots in the survey. Although a fixed receiver geometry is a natural application of this method, few surveys (such as marine streamer) use this geometry. Moving receiver geometries are the common practice in marine and land surveys. Unfortunately, the simultaneous source method using an L2 objective function can not be easily extended to non-fixed (moving) receiver geometry in a straightforward manner. This is because the recorded data are deficient in traces compared to the simulated data generated from an encoded source. We develop a new approach to overcome this problem and propose the use of a cross-correlation objective function instead of the conventional L2 objective function to invert non-fixed spread simultaneous source data. We demonstrate our methodology using a marine streamer synthetic example.
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A New Method to Remove the Moveout of Azimuth Anisotropy Based on Difference
Authors H. Q. Li, S. P. Peng, D. K. He, H. L. Xian, J. W. Gou and F. Y. ChenThe paper introduces the difference method to analyze and remove the azimuth moveout resulted from anisotropy due to that correlation delay times varying with azimuth satisfy the hypothesis of the difference method. According to the testing from the pertinent example seismic data from a radial acquisition geometry based on an EDA media, the new method proposed is valid and implemented simply.
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Seismic, Gravity & Well Log Data Integration into 3D Model Gives an Impetus to Hydrocarbon Exploration, NE Ukraine
Technology of integral interpretation for geological and geophysical data (including seismic, well logging and gravity data) within a single 3D model is shown as an effective tool for oil & gas exploration. The case study is given for the Molodvska prospect in the Dnieper-Donets basin Northern Flank, NE Ukraine.
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Study of Asphaltene Deposition in Porous Media due to Carbon Dioxide Injection
Asphaltene deposition is common problem in petroleum industy during oil production, transportation and refining processes. The deposition of asphaltene in petroleum reservoir during production can cause formation damage and productivity decline. In this study, the kinetics of deposition of asphaltene from oil during CO2 flooding has been studied experimentally and theoretically. An experimental setup designed for studying the asphaltene deposition in porous media and its effect on petrophysical properties of media due to carbon dioxide injection.The set-up is designed to work under representative reservoir conditions up to 15000 psi and 120 ºC. This setup is a high-pressure, high-temperature coreflood with the main part of high-pressure cylinder that can be placed by the core or sandpack.The results showed that asphaltene deposition in porous media increases the pressure drop and decreases the permeability of the medium. Injection rate, temperature and concentration of CO2 and asphaltene have the main effect on the asphaltene deposition process. The asphaltene deposition increases as temperature and concentration increase.
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Hydrocarbon Potential of the Carboniferous – Lower Permian Total Petroleum System in the Polish Part of the SPB
Authors B. Papiernik, W. Górecki, T. Maćkowski, B. Reicher, D. Botor, W. Burzewski and G. MachowskiA better understanding of the shift of the eastern Paratethys from an open sea to a restricted estuarine system recorded in the Paleocene-Miocene interval of the eastern Paratethys is necessary for understanding the tectonic evolution of this area. Detailed geochemical characterization offers insights not available through traditional methods, and highlights the complicated history of these strata that is so often oversimplified. Additionally, there is substantial evidence for significant terrestrial input throughout the Oligocene-Early Miocene. All of these factors suggest that the Kura Depression underwent a different history than other parts of the Paratethys, including the South Caspian Basin to the east. This has important implications for the tectonic evolution of this area, which records the effects of the Arabian-Eurasian collision and, eventually, the separation of the Caspian Sea to the east from the Black Sea to the west. Additionally, the suspected differences between geochemical character of the source rock where it is exposed versus deeper in the basin where it is generating petroleum are highlighted, suggesting caution in the direct application of outcrop data to basinal petroleum generation models.
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The Advantages of Pre-stack Inversion in Heterogeneous Carbonate Reservoir Prediction - A Case Study from Tarim Basin, China
More LessWe present a numerical evaluation of the seismic response due to fluids in the pore space of coalbeds for the Corbett Field, located 145Km to NW of Edmonton, Alberta, Canada to simulate the replacement of brine by methane in coalbeds. We use Palmer and Mansoori analytical model and Gassmann equation to generate synthetic seismograms to evaluate seismic as a monitoring tool for methane production. In the Corbett Field the targets are two coal seams of the Mannville Group, the Main Seam and the Lower Seam. Based on sonic and density log from the well 100-03-22-062-06W500 of the Corbett Field, we perform a fluid simulation to make an assessment of its production forecast in an 8 years period and a fluid substitution to estimate the variation of the seismic properties during production. We use the Gassmann equation to substitute 100% brine (initial state) in the pore space of Main Seam and Lower Seam by a combination of brine (82%) and methane (18%) and then we generate the synthetic seismograms. As the result, synthetic seismograms show, the Main and Lower Seam as a single unit and the substitution of brine by methane did not generate a significative response.
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Technology and New Ways of Working open up Pri-Caspian Basin frontier opportunities
Authors Christian Bukovics and Ben HillierThe Pri-Caspian Basin straddles the border of Russia and Kazakhstan and is one of the major oil and gas basins
in the world, with many giant fields and discoveries, and very substantial remaining exploration potential
(estimated by the USGS to be in the order of 15 bln boe). Shell has had an active presence in the region for more
than 15 years and has participated in a number of ventures, most of them still ongoing (see Fig 1), resulting in
eleven declared discoveries.
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Sedimentology of Early Aptian Reservoir: Dunga Field, Mangyshlak Basin, Kazakhstan
Authors EdwardC. Cazier and S. George PembertonThe Dunga field is located on the eastern coast of the Caspian Sea in western Kazakhstan, about 50 km north of
the city of Aktau. The field is unique in that it is a Cretaceous oil reservoir in a province of mainly Jurassic oil
and gas reservoirs.
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Hydrocarbon prospectivity of the Iranian sector of the Caspian Basin
More LessThe South Caspian basin is an underexplored basin in its Iranian segment. The relative scarcity of offshore
exploration wells is largely due to the overall water depth conditions in this part of the basin. The Iranian sector
of the Caspian Sea has the deepest water, at approximately 1,025 m (Fig. 1). Systematic petroleum exploration
activities have been started only in the past 50 years in the Iranian side. In contrast, some of the other Caspian
countries, such as Azerbaidjan, explore and produce in their part of the Caspian Basin for more than 150 years.
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Kashagan Field, Kazakhstan, and the Use of Petrophysical Rock Typing for Improved Reservoir Quality Prediction
Authors D. McGehee and R. HuertaKashagan Field is located in the Kazakh sector of the North Caspian Sea and is one of the largest oil
discoveries made anywhere in the world in the last decade. It is one of a group of isolated carbonate
build-ups in the North Caspian Basin. Kashagan consists of two separate carbonate platforms
separated by a narrow connection (Figure 1). The field is approximately 70 kilometres long and
ranges between 5 and 20 kilometres wide. The field was discovered in 2000 by AGIP with an
exploration well penetrating mainly shallow marine carbonate facies. The field is overpressured and
contains light oil with approximately 15% H2S. It is estimated to contain approximately 30 GBO inplace
and poses significant development challenges.
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From vintage 2D to modern 3D seismic data: a case study from the Kazakh sector of the Caspian Basin
Authors Walter Kosi, Joerg Schmitz, Gabor Tari, Vladimir Tikhonov and Adrian TizleyThe North Caspian Fold and Thrust Belt of Kazakhstan lies between the Precaspian Basin to the north and the
Mangyshlak Palaeo-Trough to the south. The undeveloped Kultuk Field onshore is located along the frontal
zone of this folded belt, very close to the Caspian coastline. Poor to fair quality vintage 2D seismic (Fig. 1) and
various well data defined the traps for the Kultuk Field as low-amplitude structural closures within the Middle
Jurassic sequence. However, a newly acquired 225 km2 3D seismic data set provided not only a better
understanding of the trapping configuration within the known reservoir intervals, but it also imaged, for the first
time, the deeper structure beneath.
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Shah Deniz: Appraisal of a Giant Gas Field
Authors Tracy Love, Richard Jolly, Stephan Duppenbecker and Mike VincentExploration in the South Caspian basin discovered the giant Shah Deniz gas condensate field in 1999. With an
estimate of greater than 30 trillion cubic feet of gas originally in place, Shah Deniz is in a unique position to
allow Azerbaijan to become a significant exporter of gas. Due to its size, Shah Deniz is being developed in two
stages. Through this staged development, considerable progress in reservoir understanding has been achieved,
particularly in the areas of reservoir connectivity and hydrocarbon distribution.
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Exploration in an overpressured lacustrine petroleum system; the South Caspian Basin
Authors Greg Riley, Rashid Javanshir, Nazim Abdullayev and Stephan DuppenbeckerThe South Caspian Basin (SCB) has a long history of hydrocarbon production (Fig. 1). In the last decade the
SCB has once again achieved global prominence due to substantial export of oil and gas to world markets
through a number of major upstream and midstream projects: 1) Azeri-Chirag-Gunashli oil development, 2)
Baku-Tiblisi-Ceynan oil pipeline, 3) Shah Deniz gas development and 4) South Caucasus gas pipeline (Fig. 2).
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Geological challenges to exploration in the South Caspian Basin
More LessThe South Caspian Basin has a long history of exploration with the first oil field discovered in 1848, following
instructions from Prince Mikhail Vorontsov to “authorise new oil exploration in the Bibi-Eibat Section, Baku
District, on the Caspian Sea coast, by means of earth drills and use 1000 Roubles for this purpose” (as quoted by
Gökay, 1999).
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