GeoArabia, Journal of the Middle East Petroleum Geosciences最新文献

{"title":"Digital reservoir properties from cuttings: Case studies from tight gas sand and carbonate rocks. 9th Middle East Geosciences Conference, GEO 2010.","authors":"E. Diaz","doi":"10.3997/2214-4609-pdb.248.175","DOIUrl":"https://doi.org/10.3997/2214-4609-pdb.248.175","url":null,"abstract":"Experimental quantification of rock properties requires regular-shaped intact fragments of rock. These fragments (plugs) are cut from cores extracted from wells. Coring is generally expensive and arguably impossible where new drilling technologies (e.g., coiled tubing) are employed. One application of Ingrain’s technology was to quantify carbonate reservoir properties from drill cuttings that were collected from a deep deviated well. Naturally, the configuration of the well prevented the operator from extracting core material. As a result, digital rock physics lab was the only option to understand this reservoir and design production strategy. \u0000\u0000A large number of these cuttings were imaged, segmented, and digitally tested at Ingrain. The resulting porosity, permeability, and elastic-wave velocity were consistent with the operator’s expectation based on the well’s performance. The latest-generation CT (computed tomography) scanners are used to capture in 3-D the actual fabric of reservoir rock samples - the pore-space and mineral matrix geometry and fabric - at resolutions as high as 100 nanometers. These physical measurements which require weeks or months in a physical lab can now be completed in a matter of days, on a massive scale and on any rock material, including sidewall plugs and drill cuttings. With the rapid advances in digital rock physics technology, we also envision that complicated natural pore-scale processes (fine particle migration, formation damage, diagenesis, and chemical reactions) will be virtually simulated in the near future.","PeriodicalId":275861,"journal":{"name":"GeoArabia, Journal of the Middle East Petroleum Geosciences","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"1900-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129134179","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Deterministic versus stochastic discrete fracture network (DFN) modeling: Application in a heterogeneous naturally fractured reservoir. 9th Middle East Geosciences Conference, GEO 2010.","authors":"M. S. K. R. M. A. M. B. Travakkoli","doi":"10.3997/2214-4609-pdb.248.288","DOIUrl":"https://doi.org/10.3997/2214-4609-pdb.248.288","url":null,"abstract":"Fracture modeling is a multi-step process involving several disciplines within reservoir characterization and simulation. The main idea is to build on geological concepts and gathered data such as: (1) interpretation of faults and fractures from image log data and 3-D seismic; (2) use of field outcrop studies as analogs for conceptual models; and (3) use of seismic attributes as fracture drivers. The purpose of modeling fractures is to create simulation properties with the power to predict the reservoir behavior. This note applies the concept of discrete fracture network (DFN) in a unique and comprehensive study of fracture modeling in one of the naturally fractured carbonate reservoirs of the Middle East.\u0000\u0000A discrete fracture network is a group of planes representing fractures. Fractures of the same type that are generated at the same time are grouped into a fracture set. Each fracture network containing fractures has at least one fracture set but may have many. The simplest fracture sets are defined deterministically as a group of previously defined fractures, either as a result of fault plane extraction from a seismic cube, or as previously defined fractures. Fractures modeled stochastically can be described statistically either using numerical input, or properties in the 3-D grid. Properties in the 3-D grid can vary in 3-D and can easily be modeled using seismic attributes from 3-D seismic data. The scale-up fracture network converts the discrete fracture network (with its defined properties) into the properties that are essential for running a dual porosity, or dual permeability simulation. A simple simulation model is developed for three different grid types, using the software ECLIPSE 100, grid without DFN modeling, deterministic DFN modeling and stochastic DFN modeling. The results of the reservoir simulation indicate that cases with Stochastic DFN have a better result (history match) than cases with Deterministic DFN and the grid without DFN.","PeriodicalId":275861,"journal":{"name":"GeoArabia, Journal of the Middle East Petroleum Geosciences","volume":"22 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"1900-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121628031","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Sweet success in sour Arab reservoirs: How successful coring improved data integration. 9th Middle East Geosciences Conference, GEO 2010.","authors":"A. Briner","doi":"10.3997/2214-4609-pdb.248.027","DOIUrl":"https://doi.org/10.3997/2214-4609-pdb.248.027","url":null,"abstract":"The South Rub’ al-Khali Company Ltd. (SRAK) is an Incorporated Joint Venture between Shell and Saudi Aramco and is engaged in exploring for non-associated gas and liquids in parts of the South Rub’ al-Khali Basin. The licence area contains significant quantities of ultra-sour gas in the Jurassic Arab Formation reservoir. Acquiring accurate subsurface data forms a key objective for SRAK in its currently ongoing exploration drilling campaign in the remote and challenging environment of the South Rub’ al-Khali desert. SRAK’s fourth exploration well targeted the Palaeozoic Khuff Formation but also gathered new data from the Mesozoic ultra-sour Arab Formation, where Saudi Aramco previously discovered hydrocarbon-bearing reservoirs in the late 1960s.\u0000\u0000Over 350 ft of continuous core over the Arab Formation was cut to address the reservoir characteristics and determine the rock types, whilst downhole fluid samples and well-test data confirmed the fluid compositions. This presentation will focus on the extensive technical and operational planning and strategy that eventually led to a safe and successful coring job. It will also demonstrate how the results of the detailed and extensively planned and executed routine and special core analysis programme resulted in better interpretation of well-test data. We will also demonstrate how the detailed rock typing was used to construct new field models to update SRAK’s view of the Arab Formation hydrocarbon resource.","PeriodicalId":275861,"journal":{"name":"GeoArabia, Journal of the Middle East Petroleum Geosciences","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"1900-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115112857","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Pore network modeling: A route to improved reservoir quality assessment in Arabian reservoirs. 9th Middle East Geosciences Conference, GEO 2010.","authors":"I. Billing","doi":"10.3997/2214-4609-pdb.248.181","DOIUrl":"https://doi.org/10.3997/2214-4609-pdb.248.181","url":null,"abstract":"Frequently in reservoir quality assessment, it is that which is not easily seen which has the biggest impact on fluid-flow behavior. The work presented here looks at the problems of quantifying two very different reservoirs, the carbonates of the Jurassic Arab-D Reservoir and the clastics of the Devonian Jauf Formation, both of which are impacted by pore system attributes beyond the resolution of a standard optical microscope. We highlight the results of the 3-D pore network modeling on these samples, contrasting this with the conventional approach to porosity and permeability calculation.\u0000\u0000Studies of the Arab-D reservoirs in Saudi Arabia highlight the importance of microporosity as a significant factor affecting porosity-permeability transforms. Generally, such pores are less than 10 microns in size, but can account for over 50% of the pore volume in a sample. The more microporosity, the greater is the deviation away from the average porosity-permeability trend. Modeling of the pore network in clastics of the Jauf Formation is complicated by the texture and mineralogy of the sandstones. The grains are often covered with a thin layer of illite, comprising flakes which are oriented radially to the grain surface. High microporosity within this layer and the thin nature of the flakes results in a diffuse layer around each grain, lowering the permeability.\u0000\u0000If we wish to model and predict permeability by transforming porosity data (such as obtained from wireline logs), then it is imperative to know the amount of microporosity. Given the problems of optically imaging microporosity in carbonates and sandstones, coupled with the complexities of a three-dimensional pore system, a 3-D modeling tool was used to capture and model these samples. Thin sections and scanning electron microscope images from the samples were studied statistically in 2-D and then the characteristics of the grains were reproduced in 3-D replicating the depositional mode of the grains, their compaction and diagenesis. An algorithm for pore network extraction then built a topologically-equivalent network consisting of balls representing the pore bodies and cylindrical segments representing pore throats. Porosity and permeabilities were obtained by calculating the proportion of voids space and by applying a pore flow code using elementary mechanisms of pore filling. Additionally, the Lattice Boltzmann Method has also been used to calculate pore flow inside the 3-D image itself.","PeriodicalId":275861,"journal":{"name":"GeoArabia, Journal of the Middle East Petroleum Geosciences","volume":"53 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"1900-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116969230","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Integrated static reservoir modeling of a Khuff reservoir, North Oman. 9th Middle East Geosciences Conference, GEO 2010.","authors":"von Winterfeld, P. Bizarro, B. Laksana, I. Aghbari, M. Claps, Z. Kindi, H. V. Alebeek","doi":"10.3997/2214-4609-pdb.248.132","DOIUrl":"https://doi.org/10.3997/2214-4609-pdb.248.132","url":null,"abstract":"The Khuff Formation of the Arabian Peninsula comprises mixed carbonate/evaporitic sequences of Late Permian - Early Triassic age deposited on a widespread epeiric ramp attached to the Arabian Shield. The Upper Khuff oil and gas reservoir is characterized by lithological and reservoir quality heterogeneities as a result of both depositional history and diagenetic overprint. Further to its gas discovery and initial production, Petroleum Development Oman (PDO) has recently updated the Upper Khuff geomodel by integrating new data, such as reprocessed seismic volumes, appraisal well results, and core and fluid data.\u0000\u0000Depositional/stratigraphic modeling was carried out based on facies analysis of cores, log interpretation and outcrop analogues. This allowed a detailed description of the vertical evolution and lateral variations of the carbonate ramp, from open-marine shelf, to oolitic/skeletal shoals and mud-evaporitic tidal flats. A high-resolution sequence-stratigraphic framework was built for the reservoir zones combining subsurface data and North Oman outcrop analogues, enabling subdivision of the entire Upper Khuff into third-order sequences and characterization of the flow units in terms of depositional cycles. The resulting layering scheme has proved to be correlatable at field scale. Reservoir rock types were defined to describe the reservoir matrix behaviour combining sedimentological, diagenetic and petrophysical data. These were obtained by combining lithologies and depositional facies into one single classification scheme, thus allowing identification of rock volumes with similar reservoir quality.\u0000\u0000An appropriate Petrel grid was designed not only to capture the reservoir heterogeneity with sufficient detail, but also to prevent runtime excess. Petrophysical properties were populated in 3-D by conditioning to facies and rock types in order to capture the reservoir heterogeneities. By combining seismic fault pattern, curvature analysis and well interpretations, fracture models were generated and implemented in the dynamic simulation. The reservoir uncertainties were handled by defining their ranges and applying an experimental design process to evaluate their impact on stock tank oil initially in-place (STOIIP) and gas initially in-place (GIIP). Several static realizations were generated using combinations of these parameters. The final selection of subsurface scenarios was achieved by iteration with the dynamic reservoir simulation to capture the full range of reserves uncertainty.","PeriodicalId":275861,"journal":{"name":"GeoArabia, Journal of the Middle East Petroleum Geosciences","volume":"18 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"1900-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124862035","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Comparison of patterns of permeability anisotropy distributions in Jurassic and Cretaceous carbonate reservoirs. 9th Middle East Geosciences Conference, GEO 2010.","authors":"A. Şahin","doi":"10.3997/2214-4609-pdb.248.393","DOIUrl":"https://doi.org/10.3997/2214-4609-pdb.248.393","url":null,"abstract":"Permeability measurements in most reservoirs display strong dependency on the direction. Therefore, it is essential to determine permeability variations in different directions within the reservoirs. Such variation is generally incorporated into engineering applications as the square root of the ratio of the horizontal to vertical permeability, a parameter known as the anisotropy ratio. This ratio may vary from one zone to another and even from one layer to another in the reservoir sequence. The pattern of variation of this ratio provides valuable information about flow behavior within the reservoir. Based on the whole core data from several vertical wells, permeability anisotropy distributions in three carbonate reservoirs, including an Upper Jurassic, and two Cretaceous (lower and middle) reservoirs from the Arabian Gulf region, were determined. The open-hole log data and the whole core permeability measurements were plotted together with the calculated anisotropy ratio values to aid interpretation. Such plots were generated for each well from each reservoir providing basis for the comparison of anisotropy ratios with the corresponding porosity and permeability values.\u0000\u0000The results revealed that the anisotropy ratio distributions closely follow the corresponding distributions of permeability. The values of anisotropy ratio vary considerably from reservoir to reservoir. Upper Jurassic reservoir revealed relatively higher values of anisotropy ratios as compared with Cretaceous reservoirs. Considerable variations have also been observed within each reservoir. In Upper Jurassic reservoir, some correlation has been observed between anisotropy ratios and porosity values, indicating close relationship between anisotropy ratios and lithology. In Cretaceous reservoirs, on the other hand, no obvious relationship between anisotropy ratios and lithology has been depicted. In all cases, it has also been observed that very high values of the anisotropy ratios are generally due to unusually low vertical permeability measurements recorded in compact and undisturbed muddy intervals acting as the barriers to the vertical flow.","PeriodicalId":275861,"journal":{"name":"GeoArabia, Journal of the Middle East Petroleum Geosciences","volume":"28 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"1900-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127045368","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Spatial modeling of complex sandstone bodies to maximize reservoir contact for wells drilled in clastic formations. 9th Middle East Geosciences Conference, GEO 2010.","authors":"A. A. A. J. V. Dossary","doi":"10.3997/2214-4609-pdb.248.290","DOIUrl":"https://doi.org/10.3997/2214-4609-pdb.248.290","url":null,"abstract":"The gigantic clastic reservoirs in Saudi Arabia contain thick, prolific and continuous sandstone members; however, incremental development may include numerous laterally discontinuous prolific oil-bearing sandstone bodies intercalated with non-reservoir rocks, in the so-called stringers. The optimization of hydrocarbon production requires advanced modeling workflows to identify and predict the spatial distribution of clastic discontinuous rock bodies. This study proposes cross-validation of 3-D models with new well bores to improve future predictions. The modeling approaches include sequence-stratigraphic interpretations and identification of the depositional environment. Object-modeling and sequential indicator simulation techniques were used to produce multiple realizations of 3-D geocellular facies models that predict the geometry and location of sandstone bodies. New wells were planned and drilled based on the most probable predictions. Once a well was completed, the real data collected at the wellbore was compared to multiple geocellular realizations to evaluate an average error at each location. That error was later used to modify the facies model and workflows. The ultimate goal was to reduce uncertainty and optimize new wells planning.\u0000\u0000The proposed optimization approach, for drilling new wells, was tested in the Cretaceous Safaniya stringers member of the Wasia Formation. Upward increasing gamma-ray logging values, and upward decreasing grain size from core descriptions were interpreted to indicate fining upward sequences associated with sandstone channels. Localized crevasse splays show coarsening upward and blocky shapes on the gamma-ray. Other bodies identified are bays and mouth bars. These bodies and sequence boundaries were incorporated into an initial 3-D geocellular facies model. Object modeling was used to populate the 3-D model, with objects drawn with realistic shapes and sizes. The models were cross-validated with new drilling. Each new well provides new logging data values, which were compared to predictions from various realizations of the 3-D geocellular model, and the average error was plotted against petrophysical properties and gamma-ray derivatives. Results are summarized to recommend corrections in the geological interpretation and modeling approaches. It was concluded that a hybrid approach - combining both object and sequential indicator modeling techniques - is the optimum way to predict rock bodies with current technology.","PeriodicalId":275861,"journal":{"name":"GeoArabia, Journal of the Middle East Petroleum Geosciences","volume":"22 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"1900-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129086497","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Geological and near-surface geophysical data comparison helps integration of outcrop and subsurface data for fractured carbonate reservoirs description. 9th Middle East Geosciences Conference, GEO 2010.","authors":"Di Cuia, D. Casabianca, A. Riva, E. Forte, M. Marian","doi":"10.3997/2214-4609-PDB.248.133","DOIUrl":"https://doi.org/10.3997/2214-4609-PDB.248.133","url":null,"abstract":"The heterogeneity of fractured carbonate reservoirs invariably controls their flow performance and economic value. Depositional facies, diagenesis and fractures, their distribution, spatial and genetic relationships are the sources of the heterogeneity of storage and flow properties within these reservoirs. Understanding such spatial and genetic relationships between sedimentary facies, diagenesis and fractures is fundamental to adequately describe fractured carbonate reservoirs, model their dynamic performance and identify the most appropriate development and management strategies. Particularly for fractured carbonates, outcrops are essential sources of information, in three-dimensions and at a wide range of scales, for making plausible and useful descriptions of the elements listed above. The challenge remains the effective use of outcrops in a subsurface modelling project where the co-located information are wellbore and seismic data. We aim to tackle this challenge starting from comparing the different information provided by direct geological observation and remote sensing and the different models resulting from using one or the other dataset in isolation. \u0000\u0000We have selected a large quarry excavated within shallow water Cretaceous carbonates of the Apulian platform in the Italian Apennines foreland where the two datasets have been acquired. Geological (sedimentological, diagenetic, structural) data obtained from direct and detailed outcrop observations and measurements provide the means for building a detailed, geologically consistent 3-D model through interpolation between available 2-D exposures. Geophysical data consisting of a 3-D survey and 2-D lines acquired using ground-penetrating radar (GPR), provides more spatially continuous (albeit lower resolution and at times geologically inconsistent) geometric information. Comparison between the models resulting from the two different datasets highlights some important pitfalls related to scale, resolution, interpolation and extrapolation assumptions that modellers invariably have to make when building reservoir models with detrimental effects to the usefulness of these as prediction tools. This work provides insights on the modes of integrating outcrop and subsurface datasets for building fractured carbonate reservoirs models.","PeriodicalId":275861,"journal":{"name":"GeoArabia, Journal of the Middle East Petroleum Geosciences","volume":"105 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"1900-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124861552","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Prediction of reservoir heterogeneity and quality: Examples and lessons from outcrop analogs from Wajid Sandstone, Saudi Arabia. 9th Middle East Geosciences Conference, GEO 2010.","authors":"O. Abdullatif","doi":"10.3997/2214-4609-pdb.248.102","DOIUrl":"https://doi.org/10.3997/2214-4609-pdb.248.102","url":null,"abstract":"This study seeks to characterize the reservoir rock heterogeneity and quality using sedimentological, statistical and geostatistical approaches. Paleozoic fluvial and shallow-marine reservoir analogs from the Wajid Sandstone at outcrop in southwest Saudi Arabia are the target for this study. The impact of depositional and post-depositional processes on porosity and permeability distribution were investigated at macro- to micro-scale. The study revealed a wide range of facies, environments, textural and compositional variations at outcrop scale. The porosity and permeability distribution show variability and complex patterns most probably reflecting different scales of depositional and diagenetic influences. The complex relations among parameters may be attributed to variable interrelationships. At the macro to meso-scale these include the meter-scale stratigraphic hierarchy, depositional cyclicity and lateral and vertical facies changes. While at micro-scale petrographic features, such as grain size, sorting, matrix and cement content and type all seem to be influential. The geostatistical porosity and permeability models show some agreement and differences which can also be attributed to the aforementioned controlling factors.","PeriodicalId":275861,"journal":{"name":"GeoArabia, Journal of the Middle East Petroleum Geosciences","volume":"49 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"1900-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127613310","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Maximising recovery from thin oil columns, Part 2: Using geophysics for improved reservoir quality prediction and better drilling performance. 9th Middle East Geosciences Conference, GEO 2010.","authors":"F. Zhu","doi":"10.3997/2214-4609-pdb.248.118","DOIUrl":"https://doi.org/10.3997/2214-4609-pdb.248.118","url":null,"abstract":"Petroleum Development Oman (PDO) is currently developing a Cretaceous (Shu’aiba Formation) matrix carbonate reservoir with a transitional thin oil column of 10 to 15 m as a waterflood with over 1,000 m long horizontal producers and injectors. In-depth geophysical studies added significant value in a number of areas: improved understanding of the reservoir extent, pre-drill prediction of porosity and fractures from quantitative interpretation (QI) work and borehole seismics to accurately predict the distance from the horizontal producers to the top reservoir.\u0000\u0000An improved velocity model utilizing regional wells from a 40 km radius greatly reduced the depth uncertainties to < 0.5% and predicted an extension of the field to the southeast, resulting in a stock tank oil initially in-place increase of 20%. Quantitative interpretation volumes provided rock property and reservoir quality prediction for well placement and sequencing. The porosity distribution predicted from acoustic impedance (AI) ahead of the main drilling campaign was confirmed by the drilling results and continues to guide the well lengths and sequencing successfully. Semblance and discontinuity extractions predicted sub-seismic faults and fractures along the planned wells and improved well placement and reduced drilling risks.\u0000\u0000Borehole acoustic reflection survey, based on seismic data acquired post-drilling in the borehole with a sonic tool, proves useful in validating distance from borehole to reservoir top and recognizing sub-seismic faults. The results are used in subsequent side-track strategy, nearby well placement to reduce unswept attic oil and understanding production behavior. In conclusion, geophysics has demonstrated impacts on field extension, reservoir modeling and optimal oil production beyond routine formation structure and fault definitions.","PeriodicalId":275861,"journal":{"name":"GeoArabia, Journal of the Middle East Petroleum Geosciences","volume":"87 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"1900-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132878056","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}