An assortment of applications is as follows.

1. Ameer and Almoayved described using Baker Oil Tools' InCharge Intelligent Well System in a deepwater offshore field. The system used a single control line to penetrate the wellhead and packers. Power transmission, command and control signals and data transmission were combined in a single line that required a ¼-in diameter penetration. The control line enabled the operator to monitor and control up to 12 zones in a single well and 12 wells from a single surface control system. The operator was able to monitor temperature, pressure and flow at the sandface(s) in both tubing and annulus. The flow rates of individual zones could be selectively controlled, enabling continuous well optimization. Individual zone contribution could be allocated and water and gas breakthroughs could be controlled. Multiple zones could be pre-completed and then selectively brought on stream or shut off from the control system.
2. Consider a scenario with two main injection intervals - a relatively thin permeable layer and a thick tighter interval. Development alternatives include injecting into the top interval only (this may not provide adequate capacity) or exploiting both of the two intervals with a dual completion, dedicated wells, hydraulic fracturing of the lower interval, or injecting into both zones and tolerating crossflow. Remotely activated completions can be a means to achieve regulated injection without overwhelming crossflow by modulating the injection into the lower interval to maintain pressure parity with the top, more-receptive interval. For example, install intelligent flow control equipment between the two intervals as well as sensors to monitor the pressure in both layers. The top will be injected into without downhole restriction. The bottom layer can be shut off initially and later opened to allow a phased contribution to the bottom layer. The bottom layer can be unchoked progressively. The bottom layer, in effect, compensates for the injectivity decline in the top layer.
3. Consider another example - a tilted, two-layer injection system, with one producer and one injector. Injection takes place in the updip direction and the layers are assumed to be noncommunicating. The mobility ratio is M = 1.2. This means that the displacement is only conditionally stable. If the injection rate exceeds a critical rate, the displacement will be unstable, resulting in premature breakthrough of water (an incomplete or partial sweep of the reservoir when water breakthrough occurs). A minimum architecture to achieve a critical rate split between the two layers may consist of an intelligent control device located opposite the top layer with pressure and flow measuring capability. ... When injection is started, the isolating tool is opened gradually and the rate is monitored.
4. There is other actual field experience presented to the PWRI JIP. This was a seawater injection well located between horizontal producers. There are three injection levels. The upper and intermediate levels are controlled by intelligent values. A choke, set in a standard CM sliding sleeve, is used to control the third level. The objectives were to provide a better control of water injection level by level. There would be a net benefit in oil production through better control of zonal injection - either through pressure or improved sweep.

   The well schematic incorporated a 68^o tangent section with a 9-58-inch shoe at 6145 feet TVD (10,300 feet MD). The tangent section continued to 6595 feet TVD (11,500 feet MD) at which point there was 4450 feet of horizontal section. The seven-inch was set at 15950 feet MD.

   On injection start-up, the upper and intermediate level valves were fully opened. An injectivity problem was immediately detected in level 2. Corrective action included temporary closure of the upper level (this is the high injectivity level). Thermal fracturing was used to improve injectivity of the intermediate level. With this application (the only one currently [November 1999] using an I.C. system to manage water injection), a selective water injection profile had been identified, the original reservoir model was being reconsidered and it was possible to make ongoing adjustments to fine-tune the injection profile.

   The system was deployed in September 1998 and it is still functioning correctly. To now, the OPEX costs have been reduced to a minimum (there has been no well intervention).

5. Another operator has reported on their experience with a SCRAMS installation in one of its North Sea injection operations. Three discrete zones were designed for, as shown in Table 1.

   Table 1.   SCRAMS Choke Design

   Zone	Rate (BWPD)	Chokes
   3	7,000	15 and 20 mm
   2	5,000 - 7,000	12 and 17 mm
   1	2,000	Fixed 8 mm

   Each zone was designed as a fractured situation. Intake into each zone was planned for and regulated on the basis of zonal pressure and estimates of the fracture size. The fracture size was inferred by using a Koning-type fracture model and pressure falloff survey interpretation, when that was available.

   The system has been operating successfully. Table 2 shows the partitioning of flow into each zone as a consequence of choke adjustments during September 1999. The access to Zone 2 was increased in September 1999 and the percentage of flow going into that zone increased according.

   
   
   

   Table 2.   SCRAMS Choke Design

   Zone	Percentage of Overall Flow in Each Zone
   	Before September 1999 Zone 2 ---1/3 open Zone 3 ---2/3 open	After September 1999 Zone 2 ---2/3 open Zone 3 ---2/3 open
   3	65	52
   2	24	37
   1	11	11

Baker Oil Tools	The InForceTM system, with hydraulically controlled valves, sliding sleeves and electronic or fiber optic permanent monitoring, and, The InChargeTM system, with electrically powered and controlled valves and infinitely variable chokes and electronic permanent monitoring.
Halliburton	Halliburton's SmartWellTM systems are also remotely operated adaptive completion systems. It is possible to reconfigure a well's architecture at will and acquire real-time data without well intervention. SmartWell™ completions allow for managing downhole sensors and flow control devices in real-time via an umbilical from the surface. A SmartWellTM system will be able to determine flow rates, water cut, GOR and fluid composition from each zone, commingle production from separate reservoirs, optimize artificial lift efficiency and control production from, or injection into, zones with varying permeability. The SCRAMSTM (Surface Controlled Reservoir Analysis and Management System) is a fully integrated reservoir management system consisting of both downhole data acquisition/ flow management and surface control and data links. To date, at least fourteen SCRAMS® systems have been installed throughout Norway, the Gulf of Mexico, the Adriatic Sea and Nigeria.
Phoenix	Phoenix provided Monitoring and Control systems. "NEW ORLEANS, October 1, 2001 - Schlumberger Oilfield Services announced today that it has acquired Phoenix Petroleum Services, a leader in providing tools, technologies and techniques for optimizing production in artificially lifted wells, particularly those using submersible pumps."
Roxar	PROMAC Production Control System: This intelligent completion system was designed and built for remote hydraulic control of fluid flow to and from individual reservoir zones. It is a modularized and "low cost" assembly for smart completions, using infinitely variable downhole sliding sleeves. A range of monitoring devices can provide accurate pressure and temperature information in the tubing, as well as from the individual zones. "The Demo 2000 program will allow PROMAC units to be extensively tested at the Rogaland Research test facilities in Stavanger. Complete assemblies for two zones are to be run into 2000m deep wells, with the sleeves being operated hydraulically from the surface. To ensure for all eventualities, the system is also to be tested by surface operation from coiled tubing in a 700m long horizontal well, thus guaranteeing the diversity of the unit should hydraulics fail. An expected six week main testing period will take place in the new DIACS cell, including full functionality at extreme conditions i.e. pressure, temperature, flow and delta pressure. Final testing will see how the units withstand the conditions in severe erosional stress in a sand slurry chamber."
Schlumberger	Schlumberger also has intelligent well capabilities. For example, in November 1999, they announced successful results from their intelligent flow-control equipment below an electric submersible pump in a well in Wytch Farm, UK for BP Amoco. The installation was performed on a dual lateral redrill of the original single wellbore, which had watered out prematurely. Schlumberger installed wireline-retrievable flow-control devices to allow independent inflow from both wellbores. This completion allowed for controlling the production of each lateral from the surface without intervention. Production gains from the well were estimated at more than 500,000 barrels, and the savings in future operational costs were anticipated to be considerable. The TRFC-H tubing-retrievable flow controller system provides remotely actuated downhole control of flow from the reservoir in intelligent completions. One dedicated 0.25-inch hydraulic control line routed from the surface controls the choke section of the tool. The TRFC-E tubing-retrievable flow controller system is the primary active component in certain intelligent completions. This infinitely variable flow control valve system is adjusted with an electric signal from a surface control station. The TRFC-E system is mounted on the tubing and integrates an electromechanical adjustable choke and multiple pressure, temperature and mass flow sensors. Operating current for the system is fed through an electric cable permanently attached to the outside of the tubing.
Weatherford	With the acquisition of SubTech - Subsurface Technology AS ("SubTech") Weatherford increased its capabilities for the development, provisioning and installation of downhole "Intelligent" Well Completion Systems (DIACS) and Downhole Sensor Systems with accompanying data acquisition systems.