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Collaborating Authors
Telemetry Drill Pipe: Enabling Technology for the Downhole Internet
Jellison, Michael J. (Grant Prideco) | Hall, David R. (IntelliServ) | Howard, Darrell C. (BP America Inc.) | Hall, H. Tracy (IntelliServ) | Long, Roy C. (DOE National Energy Technology Laboratory) | Chandler, R. Brett (Grant Prideco) | Pixton, David S. (IntelliServ)
Abstract Drill pipe capable of transmitting high-bandwidth data from downhole sensors and surface control signals back to those sensors has been developed and successfully tested. The system incorporates a high-speed data cable that runs the length of each joint and downhole tool. The cable terminates at induction coils that are installed in protecting grooves machined in the secondary torque shoulders of double-shoulder tool joints at each end of the pipe. The coils are recessed in ferrite troughs that focus the magnetic field. The system is virtually transparent to standard rig procedures and offers robust, reliable operation. The paper provides background data on prior work relating to telemetry drill pipe and contrasts the results of these efforts with the new system. The new system has successfully demonstrated data transmission rates of up to 2,000,000 bits/sec. Current mud pulse telemetry is limited to 8 to 10 bits/sec. Electromagnetic technology provides data rates of up to 100 bits/sec, but suffers from hole depth and formation related electric impedance limitations. Full realization of system benefits requires further development of additional drill stem components with high-speed telemetry capabilities including HWDP, collars, jars and top drive subs. A top drive sub that incorporates the telemetry design has been successfully manufactured and tested and is described in the paper. Development efforts relating to other drill stem components are also detailed. The system has been tested in a laboratory environment and in test wells. Results of these tests along with plans for field-testing in actual drilling environments are presented. Telemetry drill pipe can improve well and field productivity by providing more complete, real-time logging information and reduce drilling time and costs and enhance well control by providing real-time downhole drilling data and early kick detection. Background Information As early as 1939, technology had been proposed to link serial drill string components to provide a network for the transmission of power and data from the bottom of the hole to the drilling platform on the surface. The two technologies most widely proposed involved the use of direct electrical contacts at each joint of drill pipe and non-contact coupling of the pipe, applying Faraday's law of induction. Both systems have proven, in the past, to be so problematic that to date neither has achieved commercial success. The direct contact methods for coupling the pipe, and the obstacles present in achieving a working system, are fully explored in U.S. Patents by Dickson, Dennison and Cunningham. These obstacles include achieving a reliable contact-surface-to-contact-surface connection in the presence of an invasive, high-pressure, abrasive, and often electrically conductive, drilling fluid. Furthermore, the dynamics of the vibrating drill string also are inimical to maintaining a reliable connection at the drill pipe joint. In 1942, D.C. Hare filed a patent application suggesting the use of inductive coupling in order to create a data link along the drill string. His system also predicted the use of condensers, rectifiers, and amplifiers to aid the transmission of the signal from one pipe to another. The chief drawback to this system was the high power necessary in order to drive the signal the length of the string due to magnetic field losses in the surrounding steel of the drill pipe. R. T. Cloud also filed a patent application in 1942 for a serial inductive coupling system. Cloud suggested the use of a v-shaped trough of a magnetic alloy for focusing the inductive signal, but he did not suggest a means for reducing the high eddy-current losses that would result from use of an electrically conductive material. In 1963, A.H. Lord proposed an improvement to Hare's patent to help reduce the power required in the transformer system. Despite the improvement in the power requirements of this system, the relatively low life of the batteries, and the difficulties associated with their installation within the drill pipe joints, probably resulted in a lack of commercial support.
Abstract Data transmission from downhole tools to the surface is extremely important to drilling engineers for real-time decision making and well economics. With new advances and innovations in downhole technologies, particularly in the areas of drilling optimization and MWD/LWD technologies, the current data transmission rates are insufficient for the complete use of all downhole data that can be acquired. Digitization of transmission systems can increase the overall efficiency and accuracy of data acquisition systems. The benefits include increased reliability and large volumes of data on which to base current and future decisions. With its innovative technology, a high-speed wired telemetry drill pipe system can achieve this. The network, consisting of embedded wires along the drill string, can achieve higher transmission rates from downhole tools to the surface in real time; it enables the complete use of technological advances in approximately the same amount of rig time as is required with mud pulse or electromagnetic telemetry systems. This paper presents a study of the wired telemetry system and describes the importance of placing an amplifier/booster system to efficiently enable the data signal transmission from downhole to the surface systems. An accurately placed amplifier/booster system is an essential part for the success of the wired telemetry system. It will address signal losses and can ensure that the integrity of essential signal parameters (such as bandwidth, bit accuracy, signal strength) remains consistent throughout the transmission path. This paper presents case studies of the factors responsible for the losses in the telemetry system and the design an optimized amplifier/booster placement system to overcome those losses to achieve the objective of efficient transmission of acquired data from downhole tools.
Abstract Drill pipe capable of transmitting high-bandwidth downhole data and surface control signals has been developed and successfully tested. The system incorporates a high-speed data cable protected in a high-pressure conduit that runs the length of the joint. The cable terminates at induction coils that are installed in protecting grooves machined in the secondary torque shoulders of double-shoulder tool joints at each end of the pipe. The system is virtually transparent to standard rig procedures and offers robust, reliable operation. The new system has successfully demonstrated error-free, data transmission rates of up to 2,000,000 bits/sec. The bi-directional system can transmit real time MWD/LWD data, as well as, send commands or signals from the surface to operate downhole tools and sensors. Full-length prototype joints have been used extensively to drill and transmit data in test wells. Results of these tests, along with plans for field-testing in actual drilling environments, are presented. Potential drilling enhancements include improved bit life, optimized casing point selection, enhanced kick detection and control, and elimination of wireline log runs and survey time to retrieve MWD/LWD data. Telemetry drill pipe can expand the potential for Underbalanced Drilling (UBD) techniques and improve the safety of UBD operations. The paper presents overviews of new concepts and technologies that can take advantage of the high-bandwidth, two-way communication capabilities of the system. Seismic-While-Drilling with the ability to look ahead of the bit, enhanced well control systems with sensors distributed along the drill string and drill string dynamics monitoring systems represent areas for innovation with the telemetry drill pipe. Telemetry drill pipe can improve well and field productivity by providing more complete, real-time logging information and reduce drilling time and costs and enhance well control by providing real-time downhole drilling data and early kick detection. Introduction The process of locating and extracting energy resources from deep within the earth is challenging. Reservoirs must be located using advanced techniques, geologic formations must be penetrated and dangerous over-pressured zones must be navigated and controlled. Precise well bore placement is essential to maximize well productivity and profitability. Hydrocarbon reservoirs can be entered incorrectly, experience formation damage that adversely affects production, overshot or even missed completely. Inaccurate drilling and imprecise downhole information can result in millions of dollars of lost and delayed production. Even more tragic is the potential for injury or loss of life due to improper drilling practices associated with inaccurate well data. As early as 1939, technology had been proposed to link serial drill string components to provide a network for the transmission of power and data from the bottom of the hole to the drilling platform on the surface. Drill String Connectivity Solution The core technology behind the telemetry drill pipe system is a passive communications link than connects discrete components together. This link consists of a ring-shaped transducer that can transmit data to another component without direct electrical contact. The ring shape is ideal for data transmission across thread tool joints since radial orientation is not required for effective communication. The non-contact feature of the coupler permits it to be encased and protected within the tool joints or connections, and thereby avoids the pitfalls inherent in previous electrical connector concepts. The system incorporates a data cable traveling the length of each drill pipe section or subassembly. The cable is protected within the pipe and tool joint, and does not interfere with mudflow or the deployment of downhole tools through the drill string. The data cable is specifically engineered to transmit high-speed data with low power loss. At either end of each section of drill pipe or drill stem component, a non-contact line coupler is employed to ensure that the data signal can be passed along to the next component.
- Geophysics > Borehole Geophysics (0.88)
- Geophysics > Seismic Surveying (0.54)
Abstract Intelligent drill string components capable of transmitting data at rates up to 2-megabits per second have been developed and successfully tested in commercial drilling applications. This paper details the lessons learned during intelligent drill string field trials, with focus on the overall network performance during drilling operations, physical handling ease and integration of existing down-hole measurement tools into the network. This is the first publication of information from such field trials, and the first discussion of down-hole tool data transmission through the intelligent drill string network. The paper includes discussion regarding the potential impact of intelligent drill string technology on the drilling and completion process. This new technology can improve well productivity, reduce drilling time/costs and enhance well control safety. The paper addresses these issues and provides a forward-looking view regarding large-scale introduction of the system and the anticipated time-line for commercial availability. The intelligent drill string system incorporates a high-speed data cable protected in a high-pressure conduit that runs the length of each joint. The cable terminates at inductive coils that are installed in grooves machined in the secondary torque shoulders of double-shoulder connections at each end of the joints. The system's design supports high-speed, high-volume, bi-directional data transmission to and from hundreds of discrete measurement nodes. As a result the system offers an opportunity to capture critical data along the full length of a drill string, not just at the bit, in addition to supporting the use of high-resolution LWD tools and providing instantaneous control of down-hole mechanical devices. The system offers robust, reliable operation and is virtually transparent to standard rig procedures. Introduction Mud pulse telemetry is the current industry standard for transmission of data from MWD and LWD tools to surface and typically functions at 3 to 6 bits/sec, rising to 12 bits/sec under ideal conditions. These relatively low data rates force multiple sensors to compete for bandwidth, limiting data density and demanding complex downhole processing systems in order to achieve modest real-time measurement resolution. Mud pulse telemetry presents several other significant barriers to data flow during the drilling process:A limited capability to receive commands from surface often results in significant non-productive time when changes in down-hole tool functionality are required. The requirement that all sensors be in close proximity to the mud pulse tool prevents distributed measurements along the drill string. The inability to transmit data when circulation stops can leave the driller blind during well-control situations. Seven years of engineering and development, funded in part by the U.S. Department of Energy, has produced an intelligent drill string network capable of transmitting data at rates up to 2 Megabits/sec. This system makes it possible to obtain large volumes of data from existing MWD/LWD tools instantaneously - greatly expanding the quantity and quality of information available in โreal-timeโ. In addition, the system design means data can be transmitted both upwards and downwards, from hundreds of distributed measurement devices, regardless of circulation conditions. Each device can be defined as a node with a unique address and can gather or simply relay data from a previous node onto the next. Network protocol software and hardware control the flow of information between devices. Since every node is uniquely identifiable, the location where events occur along the length of the well can be determined. The system's bi-directional communication architecture means not only is high-speed transmission of downhole data to the surface possible, but also commands from the surface to devices downhole or even between downhole devices can be sent, received and acted on.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.54)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drillstring Design (1.00)
- Well Drilling > Drilling Operations (1.00)
- (4 more...)
Abstract Objectives of this technical paper is to share the outcome of how deployment of high-speed high-bandwidth unconventional wired drill pipe telemetry transmission of logging while drilling (LWD) to maximize reservoir contacts in an ultra-deep clastic gas reservoir. Real-time visualization and interpretation of images from higher bandwidth (57,600 bits per second) delivered memory quality formation evaluation logs in real time for timely critical decision-making and better well placement. High-end drilling and logging technologies were used to optimize well placement in a challenging environment, including gamma ray (GR), resistivity, and density images enabling timely and full (360 deg) view of reservoir properties. The real-time near-bit GR image provided a clear stratigraphic interpretation that has been used for well placement. The deep azimuthal resistivity measurement and inversion provided critical reservoir vertical distribution away from the wellbore and guided well placement lookahead of time. The real-time density image provided hole shape information for mud weight adjustment on top of the stratigraphic information for well placement. The combination of all the above-mentioned measurements and high-speed telemetry was used for minimizing the risk associated with critical well placement decision-making and improving net to gross. The above-mentioned technologies have been successfully applied to a well placement job. The memory quality data was transferred through wired drill pipe (WDP) to the surface in real time while geo-steering through a relatively heterogeneous sandstone reservoir with lateral facies variations. The real-time data was transferred to a centralized server for advanced processing and interpretation by team members to enable critical decision-making. As a result, more than 30% net-to-gross increase was achieved compared to the average net-to-gross from existing nearby horizontal laterals drilled in the same reservoir but with mud pulse telemetry (MPT) and basic logs. The ability of WDP to transmit significantly extra images from log curves ensures higher bedding visualization and improves formation evaluation qualities, technical reliability and confidence. Real time high speed LWD data streams enhanced interpretation and subsurface geological mapping, minimizes bit trip through increase in ROP and maximizes well placement. This technology opens the gateway for any other advanced high-end LWD technology tool in the future.
- Asia > Middle East (0.49)
- North America > United States > Texas (0.29)
- Geology > Geological Subdiscipline > Geomechanics (0.94)
- Geology > Geological Subdiscipline > Stratigraphy (0.74)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.54)