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Third EAGE International Science and Applications workshop Far East Hydrocarbons 2014
- Conference date: 07 Oct 2014 - 09 Oct 2014
- Location: Yuzhno-Sakhalinsk, Russia
- ISBN: 978-94-6282-034-0
- Published: 07 September 2014
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3D Models of the East Sakhalin Offshore as the Base of FDP
By V.A. Vanin1. Уточнения трёхмерных геологической и гидродинамической моделей обеспечивают основу для расчёта прогнозных вариантов добычи и проектирования эксплуатационных скважин; 2. По результатам моделирования лучшим с точки зрения технико-экономической эффективности является вариант с бурением 3 СБОВ с ГЗ и темпом отбора 6%. Более надежным с технологической точки зрения является вариант с темпом отбора – 4%. При реализации первого варианта существует риск необеспечения начального дебита 3000 тыс.м3/сут в случае недоосвоения или потери ствола скважины при бурении; 3. Модель позволяет намечать мероприятия по доразведке месторождения
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Geological Oilfield Modeling as the Main Tool for Well Placement: Controls from Geological and Geophysical Data
Authors M.O. Vodolaga, M.V. Ivantsiv, G.G. Voykov and O.M. SivousDuring the work comparative analysis of geological models on North Veninsky field was perform. Was defined how can verify the geological model and volume and possible reserves of hydrocarbons depending on quantity of needed information. Shows the necessity for further exploration on the field based on the results of additional research on the example of the acoustic data inversion and subsequent modeling litho-petrophysical characteristics. Analysis of the all data and considered various options of exploration well design was made by author. Performed calculation of the cost-effectiveness of further exploration of the oilfield depending on the chosen well construction variant.
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Mud Gas Analyses as a Useful Tool in Differentiation of Fluid Types and Aid in Stratigraphic Correlation
Authors S. Jovanovic and A. MendozaAnalyses of mudlogging gas data can be a useful tool in clarifying ambiguous formation evaluation results and identifying fluid differences. Two different gas data sets were analyzed from the Chayvo and Odoptu fields. Raw mudlog data require two stage filtering to remove noise and lithology effects. The resulting filtered data sets from carefully selected wells (Z-44ST1 and OP-7), were used as referenced data for all other wells. Gas data were plotted using various gas ratio cross-plots to identify the most useful ratio cross-plots, to answer particular problems and questions. The gas ratio cross-plot of WH (wetness) and BH (balance) for Zone XVI wells aligned well with the fluid contacts obtained from LWD data. Filtered mud gas data can provide a quality gas data set that can be used as an aide in differentiating between different reservoir fluid types. This type of analysis can be used in clarifying ambiguous formation evaluation results, such as fluid contacts in a reservoir, reservoir compartments, effects of pressure depletion etc.
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Application of Geosphere logging tool for well placement and reservoir surveillance at Chayvo Field, Sakhalin, Russia
Authors T.L. Cogswell, M.J. Egan and V. KimGeosphere tool. From initial concept through execution and post-drill analysis the ENL Geoscience team and Schlumberger’s Well Placement Group worked closely to define and deliver the well’s objectives. During the execution phase real time decisions were being made at every stand down. Schlumberger’s well placement team was co-located at the ENL office for the duration of the zone 18 reservoir penetration, working 12 hour shifts with overlapping support. Likewise ENL geoscientists and contract operations geologists worked parallel 12 hour shifts to ensure real-time decision making was smooth and efficient.
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Petroleum Geochemistry of the Arkutun-Dagi Field, Offshore Sakhalin Island, Russia: Potential Application for Allocation
Authors S. Balandin, A. Johnson, S. Dreyfus and D. ConverseThe Arkutun-Dagi Field is offshore North-East Sakhalin Island, Russia. Production is planned to be started from this field by the end of 2014. Key uncertainties for field development and production include (1) reservoir connectivity issues due to fault segmentation, (2) reservoir quality, and (3) accurate estimates of oil-in-place due to poor seismic data resulting from the presence of shallow gas. Production allocation from the field’s commingled reservoirs can be assessed with only limited use of challenging and time consuming production logging (PLT). For this reason, an alternative method of geochemical production allocation would substantially reduce operational costs. Whole Oil Gas Chromatography (WOGC) has proven to be a very useful tool for geochemical allocation of commingled oil production (McCaffrey et al.). Recent geochemical studies of Arkutun-Dagi oils from Zones 11, 13 and 14 revealed that all the three oils have distinctly different “finger-printing” as reflected in their WOGC chromatograms (Fig. 3). It indicates a potential possibility to discern these oils in the mixture if they are produced commingled. Yet another condition needs to be met for implementing geochemical production allocation: geochemical differences between individual production zones must be greater than the geochemical differences seen within each of the commingled production zones.
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Piltun-Astokh Static Model Update on the Basis of the Sequence Stratigraphy Approach
Authors A.G. Golushko, H. de Mooij, A.A. Popov and A.G. DubokDynamic simulation of the geological (static) model for Sakhalin Energy’s Piltun and Astokh fields indicates that the model does not capture the subsurface accurate enough to allow acceptable history matching of actual production data. Since this means that the predictability of the models is low as well (which complicates proper field development) it was decided to re-build the model and replace the existing layer-based model with a facies-based one. The 3D seismic data for the Piltun-Astokhskoye field was re-processed as well since the previous model and the improved imaging was used to update the seismic interpretation based on Sequence Stratigraphic principles.
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3D Close the Loop in Petrel Used for Static Model Building
More LessAn elegant way of testing the validity of a geological “static” model is to generate the (synthetic) seismic response of the static model, compare it to the actual seismic data and then update the geological model where appropriate. The workflow to “Close the Loop between the static model and the 3D seismic” can be implemented using Petrel’s modeling and visualisation tools.
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Well and Reservoir Surveillance to Improve Geological Understanding and Optimize Field Development. Examples from the Piltun Development
Authors J. Amory, D. Zhukov, N. Fedorov, A. Beresnev and M. SumrowPiltun forms the northernmost part of the larger Piltun-Astokhoye oil, gas and condensate field, located in shallow offshore waters off the north-eastern shores of Sakhalin Island. The development targets multiple stacked oil rim accumulations within an asymmetrical anticlinal structure. The primary reservoirs are shallow marine clastic deposits of the Upper Miocene Lower Nutovsky Formation. Whilst the original Piltun-Astokh appraisal campaigns addressed the first-order field uncertainties by defining the stratigraphy, structure, reservoir distribution and quality, fluid fill and short term well in-flow performance, significant second-order uncertainties remained unresolved. Information on mid- to longer term reservoir performance was generally lacking as the development concept for the field was defined. This required planning for the acquisition of such data early on in the implementation phase. This paper explains how Well and Reservoir Surveillance data was acquired, interpreted and used to drive business decisions in the Initial, Interim and Current phases of the development.
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Implementation of Probabilistic Uncertainty Delivers Confidence in Volumetric Estimates
Authors D.V. Gluschenko, P. Webb, I. Ivantsiv, O. Timofeeva, A. Boersheim, M. Smit, A. Akhmetdinov and A. VizamoraBased on uncertainty and sensitivity analysis 3 determinisitc cases of the Lunskoye geological model were derived . These realizations represent the Proven (1P), Probable (2P) and Possible (3P) scenarios for structural framework and property distribution. The final models are used for dynamic modelling and as the basis for subsequent development decisions. As the Lunskoye field ends its sixth year of production, performance observations and drilling results will continue to demand further models updates to deliver quality history matching and forecasting capability. The new model and its workflows enable the Lunskoye team to implement these updates and assess their impact on volumes and performance quickly and efficiently
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Reservoir Detection and Delineation Using Towed Streamer Electromagnetics
Authors F. Engelmark, J. Mattsson and M.T. FaroukiFollowing a period of almost a decade, a commercial version of the Towed Streamer EM System was tested over a number of producing fields in the Norwegian and British sectors of the North Sea in October 2012. One of the most challenging tests was over the Alvheim Boa field located 2,100 m below the seafloor. The results demonstrate the system can be used effectively for reservoir detection and delineation. A new processing technique to enhance the sensitivity of CSEM data to a resistive reservoir anomaly is especially suited to the towed streamer EM system. Known as optimised Synthetic Aperture (SA) processing, when applied to the data acquired at the Alvheim Boa field, it resulted in significantly improved signal strength.
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Drilling Exploration ERD Wells in the Sakhalin Inner Shelf: Specificity and Problems
Authors R.R. Rakhmatulin, A.V. Nemcov and S.V. KoryakovskiyIn the report we consider the features, drilling problems, share experiences and pay attention to the main points for design and drilling ERD wells on the Sakhalin.
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Mud Gas Acquisition - Alignment to the Engineering Rig Design that Impact Equipment and Methods
By R.V. CorwinMud log gas acquisition techniques remained fairly constant for a long period. Modern gas acquisition techniques have improved from technical innovation, resulting in truly digital mud log gas data. Modern rig design has evolved at a greater pace than mud log gas acquisition techniques. The type of gas data acquisition equipment chosen is now more important to assure quality data is obtained. Wells examined that were expected to have similar gas readings actually had highly variable measurements. Investigation showed this variation was due to mud levels changing dramatically over short periods of time. There is a direct relation between gas acquisition equipment and rig circulation system design. A review should be done of the planned rig design and efficiencies prior to determining the gas acquisition system to be used on the rig. If a modern gas acquisition system is chosen for the first time in an area, added efforts to recalibrate these data to traditional gas acquisition should be considered to assure results.
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Planning of 3D Seismic Surveys and Drilling Locations on the Priority Objects of "Magadan-2, 3" License Areas (Northern Part of the Sea of Okhotsk)
Authors M.V. Romashov, A.V. Kharakhinov, E.V. Stepanova and O.S. VinnikovskayaIn this report the generalization of available geological and geophysical information for licence areas of the Magadan shelf of the Okhotsk Sea was made. Showing subtotals integrated interpretation of 2D seismic data, including the received in 2013 data. The evaluation of the hydrocarbon potential of a probabilistic manner and assessment of geological risks for exploration works were made for the northern part of the Sea of Okhotsk. The most promising objects for the 3D seismic surveys were selected within the "Magadan-3" license area. Goals and objectives of the exploration works for the period up to 2019 were set. Locations for the exploration drilling were selected. Reserves growth was analyzed for the case of successful drilling
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Geological and Geophysical Background for the Stratigraphy of the Okhotsk Sea and the Tatar Strait
Authors E.V. Gretskaya, N. Petrovskaya, Y.U. Rybak-Franko and L. MitrofanovaThe article covers possible changes to Unified Stratigraphic Chart of Paleogene-Neogene deposits of Sakhalin. Such changes are based on paleontological and lithological data obtained as a result of study of 34 well logs on the shelf of the Okhotsk sea and Tatar Strait. Regional unconformities were identified that divide sedimentary cover into seismic sequences corresponding to stratigraphic horizons. Seismic-stratigraphic chart of Cenozoic deposits was built.
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Geology and Petroleum Potential of the Ilpinsky and Olyutorsky Basins: New Data
Authors Y.V. Rybak-Franko, K.Y. Uporov and I.V. NokhrinaВ 2012 году в пределах аквальной части Ильпинского и Олюторского бассейнов была проведена сейсморазведка в объеме 4244 пог.км совместно с набортной гравимагнитометрией. Суммарный объем сейсмических данных превысил 7200 пог.км, а плотность сети увеличилась с 0,06 пог.км/км² до 0,14 пог.км/км².
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Correlation of Basic Unconformities in Sedimentary Cover Offshore Eastern Arctic
Authors N.A. Petrovskaya and M.A. SavishkinaBased on new seismic data acquired by Dalmorneftegeophysica JSC in 2010-2012 (Seismic Survey DRS CDP 108*, Gravity Survey, Magnetic Survey), an alternate interregional correlation scheme of basic unconformities was proposed and the age of sedimentary cover in the Chukchi, Easter-Siberian and Laptev Seas was proved. The delivered results give evidence of Late- Palaeozoic-Cenozoic age of the North Chukchi basin and Aptian-Cenozoic age of the Laptev Sea and Novosibirsk basins.
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Geology and Petroleum Potential of the fore-Sette-Daban Margin of Siberia
Authors A.M. Zharkov and L.S. MargulisTo the extent of a mantle of Predsettledanbanskaya margine of the Siberian platform contains generating hydrocarbons, oil and gas parents groups, rock masses which have reservoir features, and rock masses acting as regional cap rocks. There are direct indicators of oil and gas content as oily spots and bitums in the core. Predsettedanbanskaya margine of the Siberian platform is estimated as highly promising oil and gas content territory.
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Complete Wavefield Imaging: High Fidelity Velocity Model Building and Imaging from Dual-Sensor Streamer Data
Authors G. Rønholt, J.E. Lie, Ø. Korsmo, B. Danielsen, S. Brown, S. Brandsberg-Dahl, A.V. Mavilio, N. Chemingui, D. Whitmore and M.T. FaroukiWe demonstrate the success of combining wavelet shift tomography, full waveform inversion (FWI) and separated wavefield imaging (SWIM) for pre-stack depth migration (PSDM) velocity model building and imaging. The workflow is referred to as Complete Wavefield Imaging (CWI) as it utilizes reflection, multiple, and refraction arrivals in the dual-sensor seismic data. Wavelet shift tomography, operating on reflection arrivals, was used to update the shallow overburden in a legacy PSDM velocity model. FWI updates based on matching modelled versus observed refraction arrivals were subsequently able to resolve high resolution velocity variations associated with channels, pockmarks and gas pockets in the shallow overburden. Additionally, gathers from SWIM were generated using up- and down-going separated wavefields uniquely provided by the dual-sensor data. The SWIM approach exploits the greater illumination of the near surface inherent in the multiple arrivals. SWIM image gathers were used to validate the longer wavelength features not seen by FWI. The study illustrates how reflection, refraction, and multiple arrivals from dual-sensor data can contribute towards high-fidelity model building and imaging. Resolution of the complex shallow overburden leads to more accurate positioning and depth predictions for the reservoir, directly impacting estimation of reserves.
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Basin Modeling for Reservoir Appraisal in East Siberia: Theory and Practice
Authors T.E. Topalova and D. SpahicBasin and petroleum system modeling is an indispensable tool to examine the dynamics of sedimentary basins and their associated fluids to evaluate if past conditions were suitable for generation of hydrocarbons to fill potential reservoirs and be preserved there. Thus, modeling helps to reduce petroleum exploration risk. Schlumberger’s advanced basin and petroleum system modeling software PetroMod® predicts the extent and timing of petroleum generation from source rocks, reconstructs the basin architecture, migration pathways, locations of potential traps and accumulations, and evaluates the risk based on various geologic, geochemical, or fluid-flow assumptions (Peters et al., 2009). The Siberian Petromod® dynamic model consequently will provide time – cost effectiveness, allowing much better commercial viability of exploration. Calibrated 3D Siberian model will assure more precise assessment of future well locations across the province and will save exploration costs. Such a regional study can easily be managed by combining all capabilities of 1D, 2D, and 3D modeling in one project. The Siberian Petromod® dynamic model consequently will provide time – cost effectiveness, allowing much better commercial viability of exploration. Most importantly, a calibrated 3D Siberian model will assure more precise assessment of future well locations across the province and will save exploration costs.
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