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18th International Petroleum and Natural Gas Congress and Exhibition of Turkey
- Conference date: 11 May 2011 - 13 May 2011
- Location: Ankara, Turkey
- Published: 11 May 2011
61 - 80 of 163 results
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New Giant Hydrocarbon Dıscovery in Sirte Basin, Libya
Authors M. Zanatı, R. Sarı and H. CanalesIn January of 2002, Waha Oil Company discovered a new giant oil field in the SE region of the Sirte Basin. This discovery is situated north of Waha’s giant Gialo oil field, which produces hydrocarbon from Oligocene, Eocene & Paleocene. The new oil field is a combination structuralstratigraphical trap produced from the highly fractured Pre-Upper Cretaceous Nubian sandstones which developed on the northern flank of the Gialo Basement High. Currently, the estimated STOOIP is over five billion barrels of OIP of 43° API gravity. The exploration activities for hydrocarbons in the North Gialo area dates back to the early 60’s. In the 70’s four exploration wells were drilled in Waha acreage and the Nubian formation was tested without encountering any commercial hydrocarbon accumulation. In the mid 90’s, a new hydrocarbon entrapment concept was proposed, asserting hydrocarbon accumulation in the Nubian formation, leading to the acquisition of new 3D seismic. Based on which Waha proposed in November 2001, the spudding of the discovery well 6J1-59. The well encountered a 1600-foot gross oil column before reaching the oil water contact. To date, we have drilled 17 appraisal wells, of which 16 have tested positive for oil and gas, to delineate the extent of the reserves. In the most favorable reservoir location a 1639 foot thick oil column has been encountered. Waha estimates, given the present data, that the field covers more than 108 square kilometers. The eastern and southern extensions of the field are still to be defined by recently acquired 3D seismic data. The discovery of this new giant oil field which is in a mature exploration area and is based on an alternative interpretation of the geological and geophysical data, adds value to the potential reserves to be found in the Sirte Basin. We hope that our discovery will be taken as an exploration model by the oil industry in Libya and will instigate a new generation of giant oil fields.
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New Oil Discoveries in Area 147/3-4, Murzuq Basin, Libya
Authors A. Tandırcıoğlu, R.Ö. Temel, H. Can and Y. KumruArea 147/3-4 is located in northeastern part of the Murzuq Basin, southwest of Libya and covers an area of 2783 km2. The block is awarded to Turkish Petroleum Overseas Company (TPOC), a wholly owned subsidiary of Turkish Petroleum Corporation (Türkiye Petrolleri Anonim Ortaklığı, TPAO), in the Second International Bid Round of Libya in 2005. The Exploration and Production Sharing Agreement (EPSA) signed between TPOC and National Oil Company of Libya (NOC) became effective on December 10, 2005. The EPSA for Area 147/3-4 calls for a minimum work commitment of two exploration wells and 500 km 2D and 300 km2 3D seismic acquisition in a 5-year exploration period. The exploration period was extended for 1.5 years until June 10, 2012. TPOC initiated a vigorous exploration program in the area starting with the reprocessing of previously acquired approximately 3400 km 2D seismic data in the TPAO data processing center in 2006. In addition, TPOC acquired 573 km 2D and 352 km2 3D seismic data in 2007 and conducted detailed G&G studies and determined the hydrocarbon prospectivity of the Area. The Paleozoic section constitutes the main hydrocarbon system. Organic-rich lower Silurian “Hot shales” of Tanezzuft Formation are the primary source rock as widely recognized and proven in the North Africa. Silurian Tanezzuft Formation is also the main seal in the Area 147/3-4. The primary reservoirs are the middle and upper Ordovician glacio-marine and fluvio-deltaic sandstones of Memouniat and Hawaz formations. Furthermore, Devonian Aouinet Ouinine sandstones were tested and yielded significant amount of oil. There are several trapping types in the block such as buried hills, simple anticlines, fault bounded structures. The exploration wells drilled by TPOC tested different play types and resulted in oil discoveries. TPOC drilled a total of 11 exploration wells in Area 147/3&4 and 7 of them resulted as new oil discoveries. TPOC will acquire new 2D and 3D seismic data in 2011 and drill additional exploration wells. Furthermore, following the completion of the appraisal program, TPOC plans to put these oil discoveries on stream as early as possible.
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NATURALHY (The Potential of Existing Natural Gas Network for Hydrogen Delivery) Project Objectives and Some Results
By A. YıldırımThe defining feature of global energy markets remains high and volatile prices, reflecting a tight balance of supply and demand. Renewable energy remains a small share of total global energy use, but most renewable sources experienced rapid growth in 2009. The use of hydrogen as an important energy carrier is an essential element for global sustainable development. However, there are many significant challenges for implementing all the components of a complete energy system based on hydrogen. Urgent progress towards the development of a full hydrogen system requires a practical strategy within the context of an existing, extensive natural gas system which has resulted from substantial capital investment over a long period of time. The NATURALHY project investigates the conditions under which hydrogen (pure or as a part of a hydrogen containing gas mixture) can be added to natural gas with acceptable consequences. The main objectives of the NATURALHY project are: • to define the conditions under which hydrogen can be added to natural gas in the existing natural gas system (transmission, distribution, end use, infrastructure and appliances) with regard to: § acceptable safety risks; § benefits; § impact on the integrity of the system; § consequences for gas quality management and for the end user. • to develop technical options (particularly membranes) to separate hydrogen from hydrogen/ natural gas mixtures; • to assess the socio-economic and life cycle aspects of the NATURALHY approach, thus illustrating the real value of the NATURALHY project. The project results show that existing natural gas grid has a potential for the transmission of hydrogen. However, there are also some technical limitations for delivery of hydrogen depending on the specific local situation of the natural gas network.
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Gravitational Production Method
Authors YalçıY.n Ermiş and A. GümüşA method consisting of intersecting production wells and resulting in improved recovery in oil fields is introduced in this paper. It is called “Gravitational Production Method” and its advantages over the traditional methods are discussed.Implementation of this method is possible whenever a vertical well and a horizontal well are intersected. The aim of such configuration is to increase the production rate and hence the recovery. The advantages are numerous: both wells can be used for production purposes, the combined drainage area is extended, the gravitational pressure gain wherever a dip of stratum between wells exists helps to increase the reservoir pressure gradient and yields higher production rate, the occurance of water coning is delayed due to the horizontal part of the configuration, and finally a higher production rate becomes possible by setting the production pumps at deeper locations in wells. Although the initial investement is higher due to the additional costs for implementing the technologies involved in intersecting process of the wells, however, the rate of return is expected to be shorter because of increased recovery. The design of such method for Caylarbasi oil reservoir is discussed and the preliminary results of the field application in Batı Raman oil reservoir conducted recently are presented.
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Prediction of Temperature Change of Hydrocarbon Gases Using A Two- Parameter Z-Factor Correlation Under Isenthalpic Flash Conditions
Authors C. Uğur and Ş. YamanlarIsenthalpic expansion processes of real gases through restrictions are usually accompanied by a temperature change of the gas phase. This phenomena is known as the Joule-Thomson cooling (or heating). The temperature change depends on the initial and final pressures and initial temperature as well as the composition of the gas phase. Natural gases cool down at moderate pressures upon expansion in downhole perforations or in surface chokes whereas gas condensates may heat up when expanded at elevated reservoir pressures and temperatures. The direction and the magnitude of the temperature change may be predicted by using an isenthalpic flash calculation procedure. The constant enthalpy expansion of a real gas may result with condensation of a liquid phase due to the lowered gas temperature. In such processes, simultaneous solution of mass and enthalpy balance equations is required. If there is no liquid condensation after the expansion, the enthalpy balance equation should be solved for downstream temperature given up and downstream pressures and upstream temperature. An equation of state or a two-parameter z-factor correlation can be used to model the PVT behavior of the single phase natural gas in constant enthalpy flash calculations. Two-parameter z factor correlations are simpler to code and reduce computational time. However their accuracy in energetic computations is not well understood. In this paper, predictive capability of Abu Kassem-Dranchuk z-factor correlation is studied when used in calculating temperature changes during a constant enthalpy flash process. The results are compared to Peng-Robinson equation of state and to a leading reference thermodynamic fluid properties program results.
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Matrix Fracture Interaction in Sandstone Rocks During Carbon Dioxide Injection
Authors S. Bülbül and M. ParlaktunaThe aim of the study carried out is to investigate matrix-fracture interaction during CO2 injection. In the study, an experimental work is being carried out to understand the mechanisms of the gasoil gravity drainage (GOGD) concept by the means of CO2 injection. Experiments are conducted by using sandstone core samples and n-decane is used as the oil phase. One of the purposes of the study is to improve the understanding of the influence of a fracture on the GOGD process. In the fractured case, a space is created around the core sample inside the core holder and the space is considered as a surrounding fracture. During the experimental study, pressure, temperature and recovery measurements are conducted.
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Cap Rock Integrity in Co2 Storage
Authors C. Dalkhaa and E. OkandanOne way to reduce the amount of CO2 in the atmosphere for the mitigation of climate change is to capture the CO2 and inject it into geological formations such as depleted oil and gas reservoirs, aquifers, oceans and unmined coal beds. The most important public concern about carbon capture and storage (CCS) is whether stored CO2 will leak into groundwater sources and finally into the atmosphere or not, since CO2 at high concentration is hazardous. During underground CO2 storage, the containment of CO2 will be crucially dependent on the cap rock integrity above the CO2. Thus, it is important to assess how the CO2 might impact cap rocks, since this could control the ultimate longevity of CO2 storage. Although supercritical CO2 is normally inert, when it dissolves in water or brine, it makes water acidic. This acidic water can react with the surrounding rock minerals and thus geochemical reactions, dissolution of primary minerals and precipitation of secondary minerals, take place. These reactions can alter the porosity and the permeability and furthermore affect the sealing capacity of cap rocks. The objective of this research is to identify the geochemical reactions of the dissolved CO2 in the synthetic formation water with the rock minerals of the Sayındere cap rock by laboratory experiments. It is also aimed to model and simulate the experiments using ToughReact software. Sayındere formation is the cap rock of the Caylarbasi, a southeastern petroleum field in Turkey. The mineralogical investigation and fluid chemistry analysis of the experiments show that calcite was dissolved from the cap rock core as a result of CO2- water- rock interaction. Using the reactive transport code TOUGHREACT, the modeling of the dynamic experiment is performed. Calcite, the main primary mineral in the Sayındere is dissolved first and then re-precipitated during the simulation process. The decreases of 0.01 % in the porosity and 0.03% in permeability of the packed core of the Sayındere cap rock are observed in the simulation. The simulation was continued for 25 years without CO2 injection. However, the results of this simulation show that the porosity and permeability are increased by 0.001 % and 0.004 %, respectively due to the CO2-water-rock mineral interaction. This shows that the Sayındere cap rock integrity must be monitored in the field if application is planned.
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Chemistry of Oilfield Water and Hydrocarbon Seepage on Surface along Abu Jir Fault Zone, West and Central Iraq
Authors S.M. Awadh and M.S. BayraktutanAlong Abu Jir fault zone, Hydrocarbons were flowed in association with the spring waters on surface in Hit area. These springs rich in H2S gas which moved upward with spring water, then eventually escapes to the atmosphere. Sometimes peoples ignite gas forming mass of flam on water surface. Hydrochemistry of many spring waters were investigated. These waters characterized by very high concentrations of total dissolved solid (TDS) where SO4= and Cl- as dominant anions. Hydrocarbon accumulations also intruded by hydrostatic pressure within gypsum beds of Fatha Formation (Miocene), and can be clearly seen as piles on surface. These hydrocarbons are generated and trapped at depth and leak in detectable quantities to the surface. The geochemical anomalies are close association with the fault zone which extends of several kilometers toward N-S approximately. Bacterial degradation has been happen within the reducing zone. Water salinity and leaking gas affect the environment and reflect the specific geobotany.
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Stratigraphic Framework of the Saudi Arabian Cambrian - Ordovician Successions, and Correlation with SE Turkey in the Arabian Platform
Authors M. Şenalp and N. BozdoğanBeing an asymmetric wide basin, Arabian Plate deepens towards the east and reaches its maximum depth in the Zagros Collision Zone. The oldest Paleozoic succession is the Early Cambrian Siq Formation, a fluvial to marine deposition that consists of thick, red colored sandstones. During the Middle Cambrian, regionally Arabia and Turkey were under the shallow marine conditions represented by a carbonate-dominated sequence with clastic interbeds. Named as Burj Formation in Jordan and Arabia and as Koruk Formation in SE Turkey, this sequence is a key level in the region.
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Stratigraphic Correlation of the Silurian-Permian Successions Between Saudi Arabia and SE Turkey in the Arabian Plate
Authors M. Şenalp and N. BozdoğanSaudi Arabia, Qatar and Oman located on the Arabian Platform, produce enormous amount of gas and oil from both the carbonate and sandstones of the Paleozoic successions. The purpose of this study to make an attempt to correlate the well-established Paleozoic Sequence Stratigraphy of Saudi Arabia with SE Turkey to promote the exploration potential and in order to understand the affect of the Aleppo and Mardin type highs form stable blocks between this intraplate deformation zone.
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Miocene Stratigraphy and Hydrocarbon Potential of Northern Batman
Authors T. Özdoğan, Ö.Ç. Kaya, İ. Açıkbaş, İ. Bahtiyar and M. Siyakoates during the geological stages, have gained their final forms by the effect of the thrusts formed at Miocene and Late Miocene-today’s neo-tectonism on the Arabian Plate. At this study which is carried out within these fields, to explain the activities occured during and after Miocene, it has been focused on especially stratigraphic and depositional model and Lice Formation’s facies which the Miocene thrusts moved over, passing from marine to terrestrial has been mapped. The results of this study were correlated with ancient studies (Yılmaz and Duran 1997, Sarıdas et al. 1991, İsbilir and Dincer 1991) and the differences were found. Under the scope of this study, it is thouht that Miocene units may present source, reservoir and cap rock properties in the area.
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Problems Faced in Diyarbakır XI Region Wells and the Proposed Solutions
By Y. TengizThe area studied is located in Diyarbakır city territory inside XI. Oil Exploration and Production Region. In this study, reasons of the problems appearing in a time span and frequently faced, causing production loss and abandonment of the producing wells and consequence of those problems have been analyzed. For the wells to be drilled in the region, the points to pay attention during • Casing set depth, • Open hole logging, • Cementing, • Casing corrosion prevention, • Perforation interval selection, • Acidizing operations, reasons of rising watercut values, the effect of wrong x-y coordinate measurements, CDR logs taken minimum or none in deviated holes on preparation of misleading location maps and structural maps respectively and the consequence of these are explained. In the study, geology, drilling, reservoir, logging, production and workover data and information of total 87 producing and/or abandoned wells existing in the Southeast Anatolia, Diyarbakır XI. Region, where approximately for 40 years exploration and production activites are resumed, have been evaluated in details. Production loss during producing wells’ life span, reason/result relations of the problems causing to abandon wells have been examined and solution proposals have been presented for new wells to be drilled where similar problems can be encountered.
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Gas Seepage and Oil Resources and Their Related Reservoirs, West Rawa and East Hahitha Cities, Western Iraq
Authors F.R. Al-Rawi, T. Al-Ameri and S. M. Al-DulemyGas seepage has been taken place at shallow depth through two boreholes drilled for the purpose of ground water at west Rawa city, western Iraq. The depth reached by drilling is about 42 meters only, when gas blown out suddenly. A flame of fire to a height of 3 meters can be seen where local people put fire on it. The positions of the two boreholes are projected and their locations are along the northern fault of Anah graben. The possible source of the gas could be at great depth and has migrated to shallow depth through the faults system in the area. Also, this could be an extension of the giant Akkas gas field on the other side of Euphrates River. The same situation is also found where admixture of oil and water pumped from two boreholes drilled to depths of 117 and 230 meters for ground water purposes at east Haditha city, south of Anah graben. Such gas and oil indications may be used and encourage oil companies to consider such area in Al-Jazzera region for further studies and could be prolific reservoirs. The two regions are situated to the east of Euphrates River where there are series of large grabens crossing the region and at the same time most attentions for oil and gas explorations are concentrated to the west and north of them. Akkas gas field to the west has a dry gas at depths of 3570-3650 meters, while to the north, Khalesia well showed also gas. Seismic sections around the two regions in addition to the information from many deep boreholes drilled in the adjacent areas indicated the existence of large variations in the formation thicknesses and their continuation which are characteristics of the Paleozoic sequence in western Iraq. The expected hydrocarbon reservoirs in Al-jazzera region are within the Paleozoic formations as in the Akkas area and Anah graben.
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Co-Combustion Performance of Oil Shale and Biomass Fuels
Authors E. Özgür, M.V. Kök, B.G. Miller and S.F. MillerCo-combustion performance of two oil shales and four biomass types were investigated. Differential scanning calorimeter and thermogravimetric analyser were used to analyze the samples. The oil shale samples are from Ulukışla and Himmetoğlu regions in Turkey. The biomass samples used in the study are hazelnut shell, wheat bran, poplar, and miscanthus. The aim of this study was to evaluate the co-combustion performance of oil shale and biomass at different biomass proportions (10, 20, and 50 wt.%) in blends at three different heating rates (10, 30, 50 oC/min). The ignition temperatures of the parent fuels and blended fuels were investigated to identify any improvement in combustion performance with the addition of biomass. All results were investigated statistically to identify possible relationships between ignition temperatures and physical properties of the fuels.
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The Element Enrichments of the Rocks Rich in Organic Matter around Karanlıkdere (Göynük / Bolu)
More LessThe study area is located at southwest of Göynük (Bolu) in Paleocene-Eocene Hatıldağ Formation. A Scaled Stratigraphic Column has been done with 323 m thickness and total of 113 samples were collected from study area. Interbedded oil shale, bituminous marn and limestone layers are dominant throughout the stratigraphic section. The geochemical analyses were carried out on collected samples and the contents of major, trace and REE (Rare Earth Elements) have been determined. The element enrichments of bituminous rocks were determined in studied area within the scope. Obtained element abundances were correleted with the organic rocks belonging to the certain earth’s redox/sulfidic depositional enviroments and the amounts of enrichment were determined. Considerable element enrichments in studied area are Ti, Fe, Mg, Ca and K as major elements and As, Cr, Mn, Ni, Rb, Sr and Zn as trace elements.
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Search of a Sustainable Solution to the Energy Problems of Turkey
By İ. PalazIt seems quite clear that petroleum will remain significant in the energy make up for the world in the 21st century. The petroleum industry is old, dirty, and unpopular but alternatives appear almost as illusive now as before anytime in the history. It is clear therefore until a viable alternative becomes available, we must continue to meet all challenges this industry presents. We know it works and if we continue to meet challenges we can sustain our way of life as we know now. This is by no means to stop searching for alternatives or stop diversifying energy solutions. Turkey’s energy is met by nearly 60% oil and natural gas. Turkey depends on imports by 95% and 97% oil and natural gas respectively. Volatility in the global oil price not only impacts oil consumers but also oil indexed natural gas consumers in every segment of the entire population. These combined with the fact that Turkey is increasingly becoming addicted to natural gas puts Turkish economy overly sensitive to global oil price. Turkey has a vibrant growing economy with young population presenting itself as one of the most promising countries in the world. Vulnerability of Turkish economy to oil prices hangs over its potential as dark clouds. The questions we must ask at the moment are where Turkey would be at when oil is $175/bbl or then, $200/bbl? Turkey has to find solutions to oil and gas dependency on foreign oil and gas. Are there solutions? How to eliminate this dependency or how to reduce it in the near term while aiming in the long run for independence? The fact is when we look at the other economies in the world Turkey is not alone as there are large number of countries with growing economies and with significant oil and gas import dependency hence we may adopt some of the solutions other have implemented.
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History Matching of Well Test Pressure and Geostatistical Data by Ensemble Kalman Filter Method
Authors M. Onur and Ö.İ. TüreyenIn recent years, the ensemble Kalman Filter (EnKF) method has become popular due to its favorable computation speed over the gradient (such as Gauss-Newton and Levenberg Marquardt) based methods in history matching and quantification of uncertainty in performance predictions for oil and gas reservoirs. In this work, we examine the use and applicability of EnKF method for history matching of well test pressure and geostatistical data and for performance prediction using the estimates of reservoir parameters obtained by EnKF history matching. For our investigation, we use a forward or direct model based on pressure diffusion for a slightlycompressible, single-phase fluid flow in a three-dimensional porous medium, where it is assumed that the viscosity is constant, and combine this forward model with the EnKF method for performing history matching. We demonstrate the advantages and disadvantages associated with the EnKF method by considering synthetic example applications. The results indicate that the EnKF method looks promising, particularly due to its superior computational performance compared to gradient based history matching methods for history matching of well test and geostatistical data in heterogeneous reservoir systems, but the number of ensembles to be used, and the prior variogram to be chosen to generate ensembles seem to be critical. Some guidelines are also given for effective use of EnKf method.
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3D Geostatistical Model of the Alt Sinan Reservoir in the Batı Kozluca Heavy Oil Field
Authors S.T.T. Kamanlı, Y.Ş. Karakeçe and M.Ö. TürkmenB.Kozluca Field is located within the boundaries of provience of Şırnak in southeast Anatolia. The field was discovered in 1984 and began oil production in 1985. B.Kozluca is a heavy oil field with the gravity of 12.6 0API. The basis of this study is based on reservoir modelling and simulation study created in 2001. By using data of 12 wells drilled after 2006 and updated structure contour map; detailed 3D geological model was created with geostatistical methods. 3D geological model was created with “PETREL” software. Wells, log data, structure surface of Alt Sinan Formation, fault models and sedimentological studies were input into the model. Main reservoir rock is Alt Sinan carbonates. The formation is divided into three different flow units according to the log data and petrographic facies. Variogram maps has been created by using petrophysical properties of wells. Petrophysical properties on the basis of flow unit, were distributed to area as three-dimensional. And orginal oil in place was calculated. This model will be input to run the simulation.
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3D Reservoir Model of the Bozova Oil Field
Authors M.Ö. Türkmen, C. Çetinkaya and Y.Ş. KarakeçeBozova Field is located in Bozova Town in the province of Şırnak in South East Anatolia. Oil production in the Bozova Field, which was discovered in 1995, is made from a horizon called Reservoir Interval. This interval between Alt Germav Formation and Karababa-C Formation is made up of bioclastic limestone with intragranular medium porosity having a thickness ranging between 27-40m. In Bozova Field, 8 wells have been spudded up to date and 5 of these wells have been completed as oil producers. In this study, detailed 3D reservoir model of Bozova Field is formed based on the Reservoir Evaluation Study of Bozova Field which is carried out in 2002 by TPAO Production Group. All the available well and well log data, updated Reservoir Interval surface map, fault models and sedimentological studies were implemented in the model. Petrophysical parameters which are calculated from well logs are upscaled according to flow units and are distributed to the modeling area. These distribution maps are utilized in the oil in place calculation of the field. Constituted model is in usage in ongoing simulation and uncertainty studied related to the Bozova Field.
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Uncertainty Evaluation Through Ranking of Simulation Models for Bozova Oil Field
Authors M.M. Tonga, S. Akın and Ş. DüzgünProducing since 1995, Bozova Field is a mature oil field to be re-evaluated. When evaluating an oil field, the common approach followed in a reservoir simulation study is: Generating a geological model that is expected to represent the reservoir; building simulation models by using the most representative dynamic data; and doing sensitivity analysis around a best case in order to get a history-matched simulation model. Each step deals with a great variety of uncertainty and changing one parameter at a time does not comprise the entire uncertainty space. Not only knowing the impact of uncertainty related to each individual parameter but also their combined effects can help better understanding of the reservoir and better reservoir management. In this study, uncertainties associated only to fluid properties, rock physics functions and water oil contact are examined thoroughly. Since sensitivity analysis around a best case will cover only a part of uncertainty, a full factorial experimental design technique is used. Without pursuing the goal of a history matched case, simulation runs are conducted for all possible combinations of: 19 sets of capillary pressure/relative permeability curves taken from special core analysis data; 2 sets of PVT analysis data; and 3 sets of water oil contact. As a result, historical production profiles from 114 cases are presented for screening the impact of uncertainty related to aforementioned parameters in the history matching of Bozova field. The reservoir simulation models that give the highest match with the history data are determined by the calculation of an objective function; and they are ranked according to their goodness of fit. This study constitutes a solid basis for further studies which is to be done on the selection of the best matched models for history matching purposes.
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