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Second EAGE Workshop on Geosteering & Well Placement
- Conference date: 22 Sep 2013 - 25 Sep 2013
- Location: Dubai, United Arab Emirates
- ISBN: 978-90-73834-54-5
- Published: 22 September 2013
21 - 33 of 33 results
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Enriching the Static Earth Model through a Near-wellbore Structural Modeling Workflow Combining all Horizontal Well Data
The static earth model is the centrepiece of field development, from initial reserves evaluation to well planning to production and recovery optimization. Also, the static model is most often the main source of information into the well placement pre-job model. However, while it was always agreed that the findings of a well placement job should be used to refine the original model, up until now, enriching the static model was not offered as a mature service by the providers of geosteering solutions and interpretation. This paper and presentation introduces a new workflow combining LWD information from borehole images and deep boundary mapping services (possibly from several wells in an area) into a near-wellbore 3D structural model supporting all available data. The 3D near-wellbore structural model workflow is an important contribution to workflows closing the loop from horizontal logging and well placement back to the reservoir model update.
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Biosteering in Margham Field, Onshore Dubai - A Case Study on Significant Updating of the Static Model During a UBCTD Campaign
Authors A. Henderson and P.R. MarshallFollowing successful introduction to the Middle East of underbalanced, coil tubing drilling, with biosteering (use of microfossils from cuttings samples to identify individual layers within the reservoir succession by reference to field-specific zonation schemes) as the geosteering method of choice, a campaign was planned for 2006 in the Margham Field, onshore Dubai. The field, discovered in 1982, had been developed by means of conventional drilling of 17 vertical and 2 deviated wells into Lower Cretaceous carbonate reservoirs over a period of more than 20 years. From the outset, it had been understood that the field was tectonically and structurally complex, forming part of the arc of thrustaffected structures that occur to the west of the Oman Mountains. Conventional biostratigraphy had assisted in early interpretation of major faulting in the Tertiary and Upper Cretaceous sections above the reservoirs, but seismic resolution was unable to clarify any degree of faulting within the Lower Cretaceous.
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New Technologies for Well Placement in Complex 3D Scenarios and Full Integration with Geo-models
Authors D. Omeragic, V. Polyakov, C. Dupuis, Y. Chen, B. Brot, S. Shetty, T. Habashy, T.L. Flugsrud and T.L. FlugsrudWe present enabling technologies for well placement in 3D scenarios: advanced modelling and inversion framework needed to interpret the data in complex scenarios, ran on demand as a service on Grid computing infrastructure and fully integrated with reservoir geo-models.
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Advanced Geosteering on Example South Tambey Field
Authors M. Sharov, E. Bondarev and O. LeontyevaNow possibilities of new approaches in geosteering application for drilling horizontal wells are studied. As it is widely known already, the modern technological instruments allows to carry out azimuthally three-dimensional measurements in a well, being focused on definition of structural elements of a bedding of layers and measurement of distances to layer boundaries in real time. Information received during drilling together with its structural and petrophysical interpretation allows trying new approach which can possible to call three-dimensional geosteering.
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Multiple Approaches of Geosteering and Well Placement
By M. SarrajOptimum development plans for major oil and gas fields require solid integrated subsurface description. Defining geological, petrophysical, reservoir engineering, and drilling uncertainties is essential to select the optimal development concept for reservoir depletion plan. Hence, well placement and geosteering of injector/producer horizontal wells has a significant impact on maximizing reservoir contact and thus exploit productivity and sustainability of new delivered wells.
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LWD and “DTB” Technology Pushing Subsurface Understanding beyond Conventional Limits in a Heavy Oil Belt, India
Authors C.J. Keot, P.K. Dubey, N. Sanjay Kumar, A. Walia, N.S. Rao, A.K. Singh and R.R. KumarThe northern part of Cambay basin, western India, is characterized by a heavy oil belt. A thermal EOR method widely known as In-situ Combustion (ISC) was adopted in this belt to enhance oil recovery. To capture EOR displaced oil and also to improve primary recovery, horizontal wells are being planned and drilled for last 8 years in this belt. Initially horizontals were drilled with MWD technology only but in 2011, LWD technology was introduced. A primary driving force for this technology switch was to use LWD data in real time to understand the nature of flue gas distribution and complex structural features in these fields. Additionally for drain hole sections, “Distance to Boundary” (DTB) technology was adopted for proactive navigation. LWD data from 7 infill horizontal wells drilled in this belt provided important information on flue gas saturation and distribution across these fields. This information was used to place drainholes sufficiently below the flue gas saturation level to avoid premature gassing out of wells.The use of “DTB” technology in drainhole improved well productivity owing to better controlled placement in the sweet zone. The gamut of information provided by LWD and DTB technology has comprehensively helped in better planning and recovery.
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Horizontal Well Placement in Thin Shallow Reservoir Sands for Heavy Oil Fields Development
Authors E. Rojas, J. Velasco, A. Salamanca, D. Romero and A. LeguizamonAfter a successful development campaign of Girasol heavy oil field through horizontal wells with more than 90 wells drilled and completed, the efforts and experience of the operator was directed to the development of other assets like Abarco and Under River fields. The fields are located in Colombia Middle Magdalena Valley basin and share a sequence of sandstone channels which were deposited in a fluvial environment associated to braided and meandering streams. The main target sands are located at 1,100 to 1,600 ft true vertical depth, their thicknesses range from 10 to 30 ft. and contain 11 to 13 °API oil. To maximize production, horizontal trajectories of up to 2,600 ft long, equally spaced and laterally parallel have been placed in up to five target sands from a clusters arrangement to minimize environmental impact and to develop the reservoir below the Magdalena River. Well placement under this geologically complex scenario is, in general, difficult to achieve with the use of conventional geosteering techniques, as they generally fail to identify unexpected changes in the reservoir geometry. This risk is minimized by using deep, directional electromagnetic measurements while drilling, allowing a reservoir geometry mapping in real- time, several feet from the borehole.
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Potential Improvements for Geosteering
By H.M. BandahGeosteering pioneers started with basic technologies for well placement. In the early days, several challenges were handled individually without integrating different sources of data, which reflected negatively on the final results. Today, there have been many improvements with geosteering technologies. Yet these technologies that are being used for geosteering have some technical limitations. For example, some tools are positioned behind the bit by more than 40 feet. Besides that, integrating these technologies remains a major challenge. Also, available computer applications are limited in their capabilities to incorporate real-time subsurface data into a 3D geological model. In this paper, four ideas will be considered as potential improvements for geosteering in the future.
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Successful Approach to Push ERD Limit, Enhance Production, and Optimize Reserve Recovery of an Extended Reach Oil Field
Authors S.B. Amarjit, Z. Xiaoping, H. Yingshi, T.B. Tran, P. Halomoan and J. DenichouAn operator in offshore South China planned to develop a new field comprising multiple thin oil-bearing zones. It was decided to develop the field by upgrading an existing drilling rig on a platform rig 6 km away to drill extended reach horizontal wells. The objective was to place long lateral drains in a thin-pay reservoir. However, the foreseen high drilling torque risk within the backdrop of the drilling rig that has maximum 42,000 llbf drilling torque capacity may limit this option. In addition, subsurface challenges may highly constrain the ability to access the target reservoir optimally for production and reserve recovery optimization. This paper features successful approach using the latest Logging-While-Drilling (LWD) technology and Geosteering technique to overcome extended reach horizontal wells drilling challenges – executed under limited drilling rig capacity and highly subsurface uncertainties. The efforts described are performed in real-time while drilling and aim to place the well optimally along the thin pay zone by delineating and mapping the top and bottom pay zone boundaries simultaneously. With this ability, the lateral can be placed accurately without making unnecessary trajectory adjustment that can result in additional drilling torque.
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Proactive DTB Geosteering Technique Deliver Excellent Result in Lower Burgan Thin Channel Sand Reservoir-North Kuwait
Authors H. Haddou, S. Chowdhuri, N. Abbas, A. Khan, A.G. Tarek, M. Juyal, M. Wenang, S. Noreldeen and P. ChakrabortyDrilling of development wells in the Burgan sands involves very thin and sinuous targets. These targets are the channel sand stringers and contain a substantial amount of hydrocarbons. Optimal well placement is required to drain them in a cost effective manner. Conventional well placement has met with limited success in stringers and thus resulted in low production figures. This led to the introduction of Schlumberger’s distance to boundary mapping tool in Kuwait which has proven consistently that a proactive well placement technology can be translated into maximum reservoir contact, minimum well-bore tortuosity and a facilitator for optimal production. Due to the uncertainty that is inherently present in the distribution of the channel sands, the prediction of the azimuth of channel meander can now be confidently solidified with new deep and directional electromagnetic measurements. By detecting the upper and lower conductive shale boundaries the wells can be steered in this very challenging environment of channel sands. This well was successfully drilled using the distance to boundary mapping tool and the production test resulted above 5700 BOPD which is almost 100% above the expected production rate. This paper has also been submitted for the forthcoming SPE, KOGS conference during October, 2013, in Kuwait.
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ONGKM Field Development with Well Placement by High Resolution Data at Carbonate Environment
Authors G.P. Grebenyuk, D.M. Eremeev and A. BelyaevGeosteering of the first wells in this field was based on basic methods, neverthelesschangescamewith experience. At the end of 2012, in addition to the induction resistivity and gamma ray, was used Well Placement service based on Azimuthal Density Neutron tool& density image interpretation. Final result was significantly improved. However, this experience has allowed to allocate another shadedpoint– definition of fracturing & cavernous zones, related to filtration properties of the productive layer.In 2013 under pilot industrial activities in this field forfracture zones identificationswhile drilling one of the best service company introduced a well-placement& borehole geologyinterpretationusinglaterolog system that provides both high resolution resistivity and images. This service perfectly accomplished the task in carbonate environment of ONGKM. Post well interpretation of resistivity images allow to update static model with sub seismic faults & fracture development.
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Real Time Stratigraphy: Improving Placement of High Angle Wells using INPEFA Log Transform Correlation in Carbonates
Authors J.G. Koopmans, S.D. Nio, H. Abdul Aziz, J. Hall and M. JasserWe present a real time log processing workflow that allows confident placement of wells, especially in complex carbonate depositional sequences, by exploiting a wealth of stratigraphic information present in conventional logging data. The workflow is based on the spectral analysis of data logs that identifies a hierarchy of sedimentary cycles, controlled by orbitally forced climate change. The INPEFA Log Transform (INPEFA), which is the key process in this workflow, mathematically analyses composite waveforms consisting of various amplitudes, phases and frequencies. Geologically, INPEFA is able to predict lithofacies variability, stratigraphic discontinuities and genetic relationship of depositional sequences. Application of the INPEFA workflow to real time stratigraphy provides a framework to interpret stratigraphic sequences while drilling. The benefits of this workflow includes optimal well placement and drilling operations by using a simplified Bottom Hole Assembly (BHA) solution permitted by minimalised logging requirements. This enables operators to make fast decisions during geosteering, save costs on logging equipment and obtain a higher Dogleg Severity (DLS).
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Using Inversion of Extra-deep Resistivity Data in High-angle Wells
More LessThe ability to look deeper around the well-bore using EM induction measurements is very beneficial for proactive geosteering and optimal well placement. A deeper reading tool leads to an increase in complexity of the data and models involved. Inversion becomes a necessity in resolving multi-layer formation parameters from multi-component LWD resistivity measurements. In this paper we consider the application of advanced inversion software to common tasks in geosteering and while drilling formation evaluation with an extra-deep resistivity tool. A field case study is presented.
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