High-speed wired drill strings enable two way wireline communications between drilling and evaluation service provider's bottom-hole-assemblies (BHA) and surface systems. Compared to even the most advanced mud pulse telemetry, this new capability allows reliable communication with Rotary Steerable Systems (RSS), Measurement While Drilling (MWD) systems and Logging While Drilling (LWD) systems at data rates tens of thousands of times faster than ever before. This paper describes the system development and discusses in detail the advantages immediately attainable when complete, memory quality, drilling and evaluation data is provided instantaneously at surface while drilling. These advantages include:• increased safety by continuous downhole pressure, drill string dynamics and high rate drill string energy transmission data monitoring regardless of flow or rig state; • increased efficiency by optimizing RSS and bit performance, reducing hidden NPT, and monitoring wellbore conditions while drilling; • increase reliability by providing a redundant telemetry system and enabling the user to identify damaging drill string dynamics; • maximized productivity from more accurate wellbore placement.The paper will then further discuss how application of the system may further develop to maximize the value in accessing memory quality LWD data instantaneously via the wired pipe network while drilling. SPE 113157 Telemetry Drill String Technology OverviewFirst used in 2003, the IntelliServ Network offers an ultra high-speed alternative to current mud pulse and electromagnetic telemetry methods. The network utilizes individually modified drilling tubulars to provide bi-directional, real-time, drill string telemetry at speeds upwards of 57,000 bits per second. This greatly enhanced band-width in comparison to existing technology makes it possible to obtain large volumes of data from downhole tools (and other measurement nodes along the drill string) instantaneously, greatly expanding the quantity and quality of information available while drilling.The network utilizes a high strength coaxial cable and low loss inductive coils embedded within double-shouldered connections in each tubular joint to convey information. Signal repeaters are placed periodically along the drill string to ensure an acceptable signal to noise ratio is maintained. These repeaters serve as individually addressable nodes within the telemetry network and therefore also provide a location at which potentially valuable measurement data can be acquired. Currently available telemetry tubulars include various sizes of drill pipe (in both range 2 and range 3 lengths) 4 , heavy weight drill pipe, drill collars, drilling jars and a wide array of other bottom hole assembly components.The key physical components of this telemetry network are illustrated in FIGURE 1 below. Additional details of the underlying network technology may be found in IADC paper "Intelligent

In many of today's high cost offshore areas, overpressured zones present significant challenges to optimizing the drilling process. Operators face a number of costly risks, including reduced rate of penetration (ROP); formation damage due to high mud weight; and health, safety, and environmental (HSE) risks associated with loss of well control.Operators commonly rely on logging while drilling (LWD) resistivity data and an overburden gradient to identify overpressured zones. The overburden pressure gradient is usually derived from offset density/acoustic data, seismic velocities, or regional overburden tables adjusted for water depth and air gap. One drawback of using only the resistivity-based approach is that formation resistivity is directly dependent on formation water salinity, not pore pressure. When drilling in close proximity to salt, operators have to take into account what effect this will have on water salinity. In such cases it would be better to use acoustic data due to its insensitivity to salinity changes. However, the real-time data quality of previous generation LWD sonic tools limited their use for pore pressure predictions.However, new LWD instrumentation in acoustic logging and pressure testing improves the reliability of realtime pore pressure predictions and ultimately improves the drilling process and reduces HSE risks.This article reviews a proactive approach for predicting pore pressure based on state-of-the-art LWD acoustic and formation pressure tools, in addition to discussing the application of the seismic data acquired while drilling.Aims of pressure management while drilling. In order to drill safely and efficiently, the mud weight or equivalent circulating density (ECD) has to be adjusted to: stabilize wellbore/provide cuttings removal; avoid kicks/shallow flows; avoid lost circulation/fluid losses; avoid additional casing strings; increase rig safety; minimize formation damage; and optimize ROP.The task of managing the ECD becomes more demanding in areas known to have uncertain pressure versus depth trends, such as the Gulf of Mexico, West Africa, and Indonesia.In brief, any combination of the following mechanisms can be responsible for the presence of overpressured zones: compaction, tectonics, and thermodynamics. Compaction-related abnormal pressure occurs when water trapped during rapid deposition is unable to escape as the overburden and the burial depth increase. The trapping mechanism is usually caused by high sand/shale sediment ratios, deposition of impermeable sediments, or clay diagenesis. There are numerous analysis methods to predict the pore and fracture pressures when compaction is the primary mechanism. Tectonic-related abnormal pressure is related to normal/thrust faulting, uplift, and salt dome emplacement. Thermodynamicrelated abnormal pressures are the result of geothermal expansion and hydrocarbon generation or cracking. Pressure analysis from tectonic or thermodynamic mechanisms is difficult and needs to be based on local knowledge of the geologic structural, s...

With the use of both azimuthal propagation resistivity main and cross component data, the resistivity anisotropy and its dip and azimuth angles of a massive formation (anisotropic shale or laminated sand) can be determined. The accuracy of the determined parameters depends on the amount of available data. A minimum amount of data are two frequency main components and real and quadrature cross components. The boundary effects will distort the solution eventually; however, the anisotropy enhanced processing will minimize the effects to extend the algorithm to a certain distance away from a boundary.

fax 01-972-952-9435. AbstractWe illustrate the use of a new technology for navigating and characterizing various types of oil reservoirs. Real-time images from Azimuthal Propagation Resistivity measurements provide a "map" of the resistivity patterns up to several meters around the wellbore. In addition, recently developed processing and quantitative interpretation techniques help guide the placement of the well and provide a new perspective of the formation.When navigating in gas drive reservoirs, the azimuthal resistivity measurement is used to maintain the wellbore at a prescribed distance above the oil-water contact. With its exponential sensitivity to distance, the measurement is able to detect even small changes in the distance to the oil-water interface. In a few instances, the azimuthal information provided by the real-time deep resistivity images indicates probable coning due to offset well production.Similar principles are applied in high angle drilling of water drive reservoirs. The deep azimuthal information allows the drilling engineer to maintain the wellbore at a prescribed distance immediately below a shale roof. The deep resistivity image from the azimuthal resistivity measurement also makes it easy to distinguish the roof from the occasional approaching shale lens.Whereas shallower reading LWD image logs (e.g. Gamma Ray and Density) only indicate a geological feature proximal to wellbore, the deep reading azimuthal resistivity measurement can provide geologic structure information at the reservoir scale. Visual displays show the subsurface surrounding the wellbore; quantitative algorithms accurately compute the distance, direction, and apparent dip for reservoir related geological events. A new conductivity unit named "Transverse Siemens" is proposed to help quantify the new azimuthal propagation measurement.

fax 01-972-952-9435. AbstractThe economic recovery of hydrocarbons from deepwater reservoirs continues to be a major challenge facing the exploration and production industry, not just contending with the multitude of market uncertainties, but also, more importantly, reservoir deliverability uncertainties associated with deeply deposited pay targets. One large field subject of this study is such, deposited in stacked Pliocene sandstones. These are high net-to-gross, with predominant very finegrained sands. The efficient sweep of the oil in place requires a detailed understanding of the network of the reservoir pore structure, and the permeability distribution and capillary bound fluids.To better understand and characterize the permeability and to help quantify the potential reserves, a novel low gradient magnetic resonance LWD tool for application on conventional drilling assemblies was used. This is a major departure from the more conventional techniques which use high gradient magnetic resonance on post-drilled wireline platforms. Advantages of an LWD approach are twofold; the wellbore is in good condition at the time of drilling, yielding high quality data, and the gain in rig time is significant.The high quality magnetic resonance dataset acquired was confirmed by overlaying with stationary measurements. The data was integrated with offset core data to normalize permeability models and saturation functions. LWD density images acquired during drilling were also used to provide detailed visualizations of the internal laminations of the turbidites, as well as a reservoir structural setting. Formation pressures and mobility measurements acquired during drilling were also integrated in the normalization process to characterize the deliverability of the sands. The resulting permeability model was used to study and redesign future development in the field. The saturation results also provide an improvement over the previous resistivity-only based saturation values, which were pessimistic due to the fine-grained structure of the reservoir sands.