A new system for the remote, interventionless actuation of downhole completion equipment has been developed to support industry needs to lower costs and preserve asset values. The traditional methods for setting a production packer employ coiled tubing or slickline to run a tubing plug. The new system provides a safe, reliable and more cost effective alternative to traditional intervention because it simply transmits acoustic pulses through the contents of tubulars to actuate one or more completion or service tools remotely in any desired sequence. The system not only decreases the time to set the packer but also extends the envelope for application to deep, extended-reach offshore environments. Since the system eliminates the need to circulate a ball downhole to set service tools during sand control operations, the operator can maintain constant hydrostatic pressure on the formation. This capability decreases completion time, intervention risk, the possibility of formation collapse against the completion string, the possibility of losing the filter cake placed against the formation, and fluid loss to the formation. To achieve the goals required for this system, three project targets were addressed: a reliable means of wireless communication, a surface control system, and a downhole power unit for completion device actuation. The design and capabilities of the new surface-operated, non-intervention completion system will improve completion economics. Introduction The continual need to strive for lower completion costs while preserving or increasing the value of the reservoir is a primary driver in the development of new technology. Several areas have been identified as offering the capabilities to achieve this goal, and the development of completion techniques that allow real time or near real time job monitoring and tools that receive commands without well intervention appear to be capable of meeting these needs. These interventionless techniques should be considered integral parts of "intelligent well" technology.1,2,3,4 The intelligent well completion concept conjures up images of completely automated, electronically or hydraulically controlled wellbore systems that allow two-way command and data transmission. Such systems rely on an umbilical system run from the surface to allow the control of downhole valves and other incrementally controllable devices. Several such systems have been placed in service to date, and while they can significantly increase a project's value, their expense can often be prohibitive. Because of this, the more routine completion operations have largely been ignored in the interventionless arena. The industry has now recognized that similar methods that can bring value to day-to-day completion operations with lower-cost interventionless techniques are also needed. The technology already exists to take features from the more complex systems; i.e., setting packers, operating sliding sleeves, etc., and apply them to projects where the economics do not justify the installation of high-end automated systems. This need has been the driver for the system described in this paper, which employs a stand-alone, battery-operated, electronically controlled hydraulic power unit that uses pressure pulses as a communication medium for setting a variety of completion equipment. This capability eliminates the need to run a tubing plug with coiled tubing or slickline. Both permanent production equipment and service tools in sand control applications can be actuated with control-line output from the downhole power unit. Initial system design has focused on the development of reliable surface to total depth (TD) communication to activate downhole devices. Job information can be relayed in near real time to the service company or operator locations by means of satellite or cellular technology during completion operations.
The Chicontepec formation, located in the State of Veracruz, Mexico has – presented a high level of difficulty in – the stimulation process. The formation is a very clayey sandstone, sensitive to water. Because of this, fracturing with proppant should be done with a gelled kerosene base fluid. This paper presents an appropriate fracturing design for this formation based on data obtained in the yield during more than 14 years of operations of this type. Also, extensive laboratory tests made on representative cores supported with computer simulations give backup to field observations.
This paper introduces new concepts for high-efficiency, high-output neutron generators for the well-logging industry, incorporating planar field ionization (FI) ion sources, which can provide for an order of magnitude higher neutron yield at a fraction of the power of conventional designs. Neutron generators for the well-logging industry primarily use electron-impact ion sources, which have low ionization efficiency and less than 10% monatomic ion production. A magnetic field or higher gas pressure is often required for improving ionization at the expense of lower reliability, average neutron yield, and large Tritium activity. The planar, FI ion source concept was investigated, and studies of a 100-µA ion-beam interaction with a thin Titanium target shows the target’s temperature at maximum operating conditions, never exceeding the Tritium desorption temperature. Particle-in-cell (PIC) simulation software was used for simulating the ion-beam transport from the planar, FI ion source, resulting in a mostly ideal beam transport covering the entire surface of the target, which reduces the target’s operating temperature and, thus, eliminates T desorption, allowing for approximately an order of magnitude higher neutron yield, higher logging speed, and a significant reduction in rig time, as well as substantial cost savings.
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