IBP213-04

CHALLENGES AND SOLUTIONS FOR INSTALLING AN INTELLIGENT COMPLETION IN OFFSHORE DEEPWATER BRAZIL Alfonso R. Reyes1, Jose Luiz Arias2

Copyright 2004, Instituto Brasileiro de Petróleo e Gás - IBP This Technical Paper was prepared for presentation at the Rio Oil & Gas Expo and Conference 2004, held between 4 and 7 October 2004, in . This Technical Paper was selected for presentation by the Technical Committee of the event according to the information contained in the abstract submitted by the author(s). The contents of the Technical Paper, as presented, were not reviewed by IBP. The organizers are not supposed to translate or correct the submitted papers. The material as it is presented, does not necessarily represent Instituto Brasileiro de Petróleo e Gás’ opinion, nor that of its Members or Representatives. Authors consent to the publication of this Technical Paper in the Rio Oil & Gas Expo and Conference 2004 Annals.

Abstract

This paper describes an atypical and challenging Intelligent Well Completion (IWC) installed in ultra deep water (1500-2000m), offshore Brazil. The well is a water injector designed to selectively control the injection flow rate in to two stacked gravel pack zones. The field is Roncador, approximately 150 kilometers offshore the North-Eastern coast of the state of Rio de Janeiro, Brazil. This application is an atypical IWC due to the long distance (~15 Km) from the production platform to the well. Intelligent wells have been installed at such distances previously but never with a direct control umbilical. Previous completions used a Subsea Control Module (SCM) or pod located in the wellhead. Reduced intervention costs are the typical driver for IWC in deep water applications, but water management is becoming an increasingly common application. The Roncador field development team has taken a novel approach by using IWC to manage water injection in an ultra deep water development. The challenge for the project team was to design an IWC system, which would accommodate the field infrastructure constraint, require minimal modification to the existing subsea hardware and ensure the necessary flexibility to locate surface equipment without the need for modification to the production facilities. The solution adopted for Roncador 35 is mainly based on an emerging ISO standard for the integration of IWC into Subsea Production Systems. The modular and expandable approach will enable extension of this solution to other wells in the Roncador field.

1. Introduction

The main challenge of this well is the use of a direct electro-hydraulic umbilical from the production platform to the wellhead: 15.5 kilometers with a water depth of 1890 meters. A subsea canister was proposed to “boost” or relay the signal from the surface to the down-hole intelligent valves. An essential element of the project was to maintain the well architecture with minimal modifications. The Christmas tree design is standardized with two hydraulic and one electrical penetration only. The IWC interval control valves (ICVs), have redundant electronic boards, each requiring one hydraulic line and one electric line (i-wire), so one of the required electrical penetrations was unavailable. A solution to this problem was found with a dual-contact, single-pin connectors. The control system at surface also represents a new focus in the remote control of intelligent wells. The production facility is a Floating Production, Storage and Offloading (FPSO) vessel. A surface control system had to be designed to be able to remotely control a Hydraulic Power Unit (HPU) on the turret of the FPSO, 250 meters away from the operators control room. This distance made it impractical for operators to maneuver the HPU to operate the hydraulic part of the system. Another important concern was the control system protocol standardization. This requires the use of an open architecture and modularity to integrate the mission critical computer components connected in a network. To accomplish this, an OPC Server and OPC Client were used.

______1 Engineer - WellDynamics 2 Msc. Electronic Engineer -

Rio Oil & Gas Expo and Conference 2004 2. Reservoir drivers

The main factors that brought Petrobras to a decision to deploy an intelligent well in Roncador field were:

• Importance of the field potential • Field Characteristics (multizones) • Field profitability • Cost reduction • Water Injection Reservoir Management • Control and Optimization of Water Injection • Possibility of performing “fall-off” tests without well intervention

Without individual control over the water injection, the injection rates would not be as desirable, producing a non-optimized reservoir sweep. If this separate zonal control had not been possible, two wells would have required to be drilled for water injection to maximize recovery from the field.

3. Well and Completion Data

3.1. Roncador-35 The Roncador field was discovered in 1996 and holds more than 2.5 billion barrels of oil equivalent. The Roncador field is one of the seven oil fields of Brazil’s . The well Roncador 35 (RO-35) is one of 11 wells (8 producers and 3 injectors) which are tied back to a central Floating Production Storage and offloading (FPSO) vessel. The FPSO Brasil is a converted tanker capable of handling a daily production of 14,300 m3/d of oil and 3 x 106 m3/d of gas, with a storage capacity of 270 x 103 m3/d liquid. The FPSO has facilities to inject up to 12,700 m3/d water. The water depth for RO-35 is 1892 meters and the perforation top is located at 1610 meters below sea level. The upper pay zone has 15 meters and the lower zones have 68 meters potential. In Figure 1 we can see the depths for the well and umbilical length.

Figure 1. Well Roncador 35, depth and umbilical distance 2 Rio Oil & Gas Expo and Conference 2004

Roncador 35 has three water injection zones. The use of an intelligent completion to manage injection into these zones is based on the importance of efficient reservoir sweep to increase reserve recovery from the Roncador field. It is fundamental to achieve a precise control of the injection rates on every zone for the operational continuity of the reservoir. The water injection rates estimated per zone will be in the range of 9,500 to 30,000 barrels per day.

3.2. Completion Design The RO-35 IWC consists of two isolated zones controlling three separate reservoir intervals. Each zone is isolated using hydraulic feed through packers and the injection rate is controlled with the use of Interval Control Valves (ICVs) with infinitely variable positions. The upper zone controls injection into the upper reservoir interval and the lower zone controls injection into the lower two reservoir intervals. The lower zone production flows through the isolation assembly stung into the lower-zone polished bore receptacle (PBR), and into the seal section of the lower shrouded ICV. The upper zone production flows around the lower zone isolation assembly, past the shroud of the lower ICV, and into the upper ICV. The upper and lower zones can then be open and closed independently.

3.3. Control System The control system is a fully integrated multidrop, redundant power and communications network, incorporating tubing and annulus pressure / temperature monitoring, ICVs with infinitely variable control, and position sensors to transmit the current position of the ICV choke to the surface. The distributed architecture control system, developed to complement the intelligent completion, was designed to reduce the degree of customization required for different IWC application environments. The control system, termed SDACS, uses common components both in surface and subsea applications and has been developed with reference to the proposed revision to ISO 13628 Part 6 covering interface to IWC (IWIS committee). An IWC controller card set provides autonomous data acquisition to be maintained from the in-well tools string as well as providing data processing, analysis and recording. A second card provides for communications interface to the proprietary protocol utilized by the in-well tools, as well as providing electrical protection to the system. Utilizing the IWC interface card set in the subsea canister allowed the implementation of a communications and power distribution system using industry standard methodologies, which are more suited to the physical layer and extended distance communications than the application of a proprietary protocol.

3.4. Tubing The upper tubing string that connects to the top of the IWC is 5-1/2" 17 lb/ft 1Cr 80 ksi BTC - Buttress Thread Casing - Range 2. The lower tubing string that connects to the bottom of the completion is a tail tattle 3-1/2” 9.2 lb/ft 13Cr New NK3SB.

3.5. Packer The high performance, retrievable, cased-hole packer has a special design for this type of intelligent completions, providing feed-throughs for up to five hydraulic control lines and instrument wires without the requirement for splicing.

3.6. IV-ICV and Control Module The Control Module / ICVs are the heart of the system. They comprise an upper section, the control module, and a lower section, the ICV. The control module provides the control and data acquisition functionality for the Control System. It contains redundant electronics, each connected to separate flat-packs containing hydraulic and electric control lines, a hydraulic manifold to distribute hydraulic power, and sensors for pressure/temperature measurement. The user sends an order to open or close the ICV from the SDACS Server at surface to the control module. The control module takes control of the hydraulic circuit to move the valve by displacing hydraulic fluid inside the piston of the ICV. The control module enables accurate valve positioning and determines the current position of the valve by the feedback from the position indicator located in the ICV, shown in Figure 2.

3.7. Filter The inline 3-stage filter of 75 microns provides an additional filtering step downstream of the Hydraulic Power Unit (HPU) filters at the surface. Fluid cleanliness is an important factor in ensuring the reliability of a hydraulic operated system. The Control Module and ICV assembly are debris tolerant in the sub 100 microns region. The filter ensures that large particles (above 75 microns) are excluded from the ICV and control system assembly.

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Figure 2. Infinitely Variable - Interval Control Valve (IV-ICV)

4. Subsea Integration

4.1. Umbilical and Communications System The distance of the direct umbilical is not common in subsea completions. Generally, oil companies use Subsea Control Modules (SCMs) or pods to avoid the use of multiple hydraulic lines and multiple pairs in the umbilical. In the case of Roncador, Petrobras concluded that the direct umbilical connection from the FPSO to the subsea tree was the best choice. The main advantages found for this configuration is reliability and familiarization with the implementation. Another important factor is the standardization system that has brought effectiveness in the Christmas tree installations throughout the organization.

Figure 3. Direct Umbilical Configuration. 5x Hydraulic Lines and 3x Twisted Pairs.

The umbilical, as shown in Figure 3, with 5 x 3/8” hydraulic lines and three twisted pairs, extends for 15.5 kilometers from point to point. This distance attenuates the data signal of any available intelligent well control electronics. To cover this distance the data signal needs to be conditioned through an additional electronic device acting as a “data signal booster”. This device is called the “canister”. One of the factors that had to be considered was the low collapsing pressure of the umbilical control lines. This issued was resolved using a control fluid of similar density to that of the sea water to keep the differential pressure

4 Rio Oil & Gas Expo and Conference 2004 within reasonable limits. The fluid chosen was HW-443, a water based fluid that has been extensively tested and qualified for this type of applications.

4.2. Subsea Canister The use of an electronic canister structure was proposed to be mounted on one side of the Christmas tree cap. This canister has the characteristic of being ROV deployable and retrievable. The canister can also be deployed by a DSV (Diving Support Vessel). The long distance communication system has the following main components: • Topsides Canister Cabinet (TCC) for surface power & communications located at the FPSO turret. • Multipair long direct hydraulic umbilical that runs from the FPSO riser deck to the wellhead. • Canister assembly that docks over the base structure on the side of the tree cap. • Canister base structure. This is the part with the shape of a funnel. This structure is attached and bolted on one of the sides of the tree cap.

The electronics inside the canister assembly allows the data to be transferred to and from the Topsides Canister Cabinet (TCC) to the Interval Control Valves. The canister has two ROV connectors on its front plate to allow a quick connection of its two electrical jumpers to the Christmas Tree and Tree Cap. The first jumper, for the long distance communication, is routed in direction to the Cristmas Tree where it connects to the 15.5 Km umbilical. This electrical path is terminated on the Turret Umbilical Termination Unit (TUTU) at the Riser Deck in the FPSO. The second jumper, that carries the IWC protocol to communicate with the interval control valves, is routed to the Tree Cap plug redundant connector (single- pin, dual-contact), which will hook up to the Tubing Hanger receptacle. In the case that the tree cap or the canister has to be removed, the jumpers coming from the Christmas tree and tree cap will rest on two dummy connectors located on the funnel base structure. The TCC is located in a hazardous area of the FPSO turret and has to be an explosion protected cabinet (air pressurized). The TCC also provides power by the same umbilical data bus to the subsea subsystem.. The canister lands on the Christmas tree cap guided by a funnel structure that makes easier to maneuver and couple the canister assembly to the base funnel structure. One of the outcomes of the collaborative environment between Petrobras and WellDynamics was to put in practice the idea of using dummy connectors in the canister structure. This connector is prepared in such a way that permits a remote diagnostics in the whole length the umbilical, from the Turret Umbilical Termination Unit (TUTU) to the canister dummy special point. This implementation will allow a quick troubleshooting of the electrical part of the umbilical. In Figure 4 it can be seen the canister landing on the tree cap funnel structure during a System Integration Test.

Figure 4. Canister assembly and base structure.

4.3. Dual Contact, Single Penetration Connectors The Christmas tree with a single electrical penetration challenged the project team to think of new ways to transmit two electric and independent wires from the surface to the downhole intelligent tools. 5 Rio Oil & Gas Expo and Conference 2004

Due to the redundant characteristics of this intelligent completion the dual subsea connector was a must. Two conceptual designs were considered: concentric pins with two contacts, and single-pin with dual-banded contacts. Timing and operational concerns at the moment of landing the tree cap on the Christmas tree main body mandated that the best alternative was the single-pin, dual contact given the short time available for the analysis and the design. This special design provides two electrical paths for two independent circuits of the downhole intelligent control valves. The connectors are composed of a receptacle and a plug. The dual-contact receptacle is installed at the top of the tubing hanger ready to receive a connection from the plug connector. During installation, the dual-contact plug installed at the bottom of the tubing hanger running tool (THRT) is run with the Drill Pipe Riser (DPR) and will connect to the tubing hanger to perform connectivity tests. When the tree cap is landed, it connects to the tubing hanger by its own dual-contact plug. At the bottom of the tubing hanger the electrical interface from the single-penetration, dual-contact connector to the downhole instrument wires (i-wire) will use externally testable connectors.

5. Surface Control Equipment

5.1. FPSO and Equipment Distribution The FPSO Brazil is a converted tanker ship (255,000 dwt) that contains the production facilities to process hydrocarbons from 11 wells. Eight of them produce oil and two are used as water injectors. Production capacity of the FPSO Brazil is around 90,000 BOPD and 3MM cubic meters of natural gas per day, storage capacity of 1.7MM barrels of oil. The vessel can inject up to 15,000 cubic meters of water per day. In Table 1 we can see the main areas identified to locate the surface equipment for the intelligent completion. Table 1. Surface Equipment Distribution on FPSO Equipment Installed at Environment Location on Distance from HPU @ ship Winch Deck (meters) Turret Umbilical Termination Riser Deck Outdoors Under deck - 18 Unit (TUTU) Hydraulic Power Unit (HPU) Winch Deck Outdoors Turret 0 Topsides Canister Cabinet (TCC) Winch Deck Outdoors Turret 2 Electrical Swivel Upper Deck Outdoors Turret 18 SDACS Server Local Equipment Indoors Vessel Deck 200 Room (LER) OPC Client Central Control Indoors Vessel Deck 250 Room (CCR)

At the TUTU, the hydraulic and electrical ends of the umbilical are connected in a junction box. Twisted pairs are run to the canister Topsides Canister Cabinet. The high pressure hydraulic lines from the umbilical are also connected to the HPU. As the turret is fixed and the ship rotates around it, the turret requires an electrical swivel. The electrical swivel has many terminal blocks that are used for different power and communication services in the turret. The IWC uses two pairs of connectors to transmit its data back to the SDACS Server in the LER. The LER only keeps rack computers, digital controllers, signal conditioners, power regulation equipment, network equipment, net oil computers, etc. No personnel are allowed in this area unless configuration or maintenance is needed. The FPSO operators supervise the processes in the Central Control Room or CCR. Here is where most of the computers or GUI terminals are located. The intelligent well is controlled from this room by means of a standard computer called the OPC Client Workstation with Windows 2000 installed. This computer is the front end of the intelligent well and has OPC as the communication interface between the SDACS Server and the end user. The SDACS Server in the LER and the OPC Client in the CCR communicate via the automation Ethernet network. The data coming from the platform process plant will enter into PI (Plant Information) servers. Physically, these servers are located in the main office and they concentrate and distribute all the information to all the business units. The communication link is satellite or via radio-modem with high transmission speeds.

5.2. Remote, Automated Hydraulic Power Unit (HPU) The ample space in the FPSO and the sparse distribution of the equipment on the deck produced the necessity of adding some remote capabilities to equipment. For instance, the Hydraulic Power Unit (HPU) located on the Winch Deck of the turret, an important part of the IWC, had to be transformed in a non-dependant of manual operation or in- situ supervision given the distance, 250 meters, from the operators control room (CCR).

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The HPU for this IWC is fully automated, has electric motors and pumps, electronic sensors and a digital controller that enables it to be remotely controlled from the CCR. Also, the sensors send data through a Programmable Logic Controller (PLC) mounted inside the HPU. The HPU, as another module in the system, communicates to the SDACS (Surface Data Acquisition and Control System) Server computer in the LER via a RS-485 cable that passes through an electrical swivel in the turret.

5.3. The SDACS Server The Surface Data Acquisition and Control System or SDACS Server is located in the Local Equipment Room (LER). This computer provides the background computing power necessary to send commands, retrieve, store, display, and distribute the data coming from the downhole interval control valves. The SDACS Server acts as a master for the canister Topsides Canister Cabinet and the PLC of the Hydraulic Power Unit, both subsystems located on the winch deck of the turret. From this computer the operator can also control the HPU, open or close the downhole ICVs, and configure the whole data acquisition system. The SDACS Server communicates with the canister topsides cabinet and the PLC, using the Modbus protocol via RS-485. To communicate to other computers in the FPSO connected to the network, the SDACS Server uses OPC (OLE for Process Control). The SDACS Server is not intended to be the end-user interface; it is kept unattended in a rack at the LER and is only accessed when some configuration or maintenance routine is necessary. To perform the task of a Graphical User Interface (GUI) there is one computer used for this purpose: the OPC Client, which is decsribed below. The SDACS Server, that at the same time services the topsides canister cabinet and the HPU as a Modbus master also attends the OPC communication as OPC Server. The OPC Server “publishes” the OPC tags throughout the network and the OPC Client knows that it can use these tags to send and receive commands and data. The data that the OPC Server collects in the FPSO makes this information available through the automation network. This system can be connected to other supervisory terminals located in other platforms, or with another OPC client located into the reservoir engineer’s situation room that could also be connected to other IWC monitoring systems. The reservoir engineer will analyze and model the reservoir behavior acting whenever necessary in the well control to correct the system.

5.4. The OPC Client Petrobras is making efforts to establish a common interface between all the digital and computerized control systems in the oilfield to transmit data to the main offices onshore and in Rio de Janeiro. Part of this philosophy is to spread the implementation of OPC. This software interface will permit the customer to reduce the number of protocols present in all electronic controllers from different vendors, and to create a unique platform for data transfer, linking bottomhole, wellhead, production, injection, and plant process data. The benefits of modularity, distributed system, open architecture, and independence from proprietary protocols, are fully realized when the Graphical User Interface (GUI) of the intelligent control system is linked with the use of an OPC Server and an OPC Client. In addition to the SDACS Server, aimed to be the main GUI for low-level tasks and at the same the OPC Server, another computer with a simpler GUI, will be used for the daily operation interface in the CCR; this is the OPC Client Workstation. This OPC Workstation simplifies the tasks of the operators as it contains a minimum set of operation screens. In addition it opens the intelligent control system to distribute well information in its databases to the rest of the organization. OPC was chosen as the common communication standard to allow Petrobras to obtain remote access to the data inside their network; to enhance information integration and availability, and to avoid proprietary protocols or quasi-standard protocols. It is an industrial standard protocol fully consolidated in the control and instrumentation industry, and it is flexible: • To provide communication between the hardware and the software of all commercial supervisory systems (or SCADA packages). • to ease integration with other types of completion systems • to eliminate the use of proprietary protocols that limit or make difficult the information integration with existent systems. OPC makes possible the integration of diverse systems that generate field information; intelligent completions, process plants, permanent down-hole gauges and other systems. This synergy in information interchange permits decisions to be taken in a fast, secure and coherent way.

5.5. Water Injection Flow Rate Calculation Estimating the water injected into each of the completion zones is a pre-requisite to effective reservoir management. Material balance between the produced and injected fluid can provide valuable information as to the characteristics of specific sections of the reservoir. For this reason one of the requirements for the completion was to be able to estimate the flow rate injected at each layer. 7 Rio Oil & Gas Expo and Conference 2004

Instead of deploying additional equipment such as a Venturi Flow meter, which may reduce the completion ID, it was decided to make use of the signals already existing in the IWC such as annulus and tubing pressure and temperature as well as ICV valve position. A couple of different methods with different levels of accuracy were investigated. The first and simpler one, presently implemented in the Roncador control system, is based on Cv curves obtained during the flow testing performed as part of the valve and flow trim qualification process. A dependency between the valve opening and Cv is described by a linear equation, which allows the calculation of flow rate as a function of valve opening and differential pressure across the valve. The second and more sophisticated methodology is based on Computational Fluid Dynamics models matched with experimental flow test. The physical phenomena regulating the flow at the valve are understood in greater details such that an accurate relationship between fluid velocity at the valve and coefficient of discharge, and pressure recovery in the annulus and split flow at the valve can be brought together into a Flow Estimation Predictive Model. The inputs for this calculation engine are the same of the Cv based system. This allows Petrobras to postpone the decision to change estimation methodology at any time in the future.

6. The impact of Real Time Data

The importance of the real time speed resides in the fact that this information can be correlated with other information originated in other wells in the same field (for instance, permanent downhole gauges, artificial lift, injection wells, etc.). This communication between wells allows the operator to have a very dynamic process. And in the near future, with the integration of the monitoring and control in real time of all of the wells in the field, the independent wells will evolve into the expected "Intelligent Field" or SmartField. The real time data has become a very important tool for making decisions. The importance resides in the integration of the information coming from different systems like 4D seismic, microseismic, etc., reducing the time that is necessary to make decisions. In the case of the integrated intelligent control valves, in addition to the choking characteristics, real time monitoring of reservoir pressures, temperatures, and equipment diagnostic data reports can be used effectively in reservoir modelling. This can assist in prediction and adjustment of the water fronts behavior, injection rates, and static and dynamic levels that help to define artificial lift methods. The dynamic characteristic of this type of IWC implementations brings the benefit of responding in real time, as more and more information becomes available allowing one to make important decisions on new well projects, and direct and indirect control of the reservoirs.

7. Conclusions

7.1. Lessons Learned This intelligent completion demonstrates that long distances with direct control umbilical are achievable using an electronic canister to relay control signals the distance from the surface to the downhole control valves. In cases where a single electrical penetration exists in a Christmas tree and two electrical wires are needed, a dual-contact connector is a viable solution. Other solutions to this problem are possible, but would require further investigation. With this particular approach, careful consideration should be given during installation to align the tree cap plug to the tubing hanger receptacle connector. A collaborative environment between the operators and the supplier brings creative solutions that create value, in addition to that realized with the implementation of the IWC. Examples of these solutions are the modification of ROV dummy connectors to test the umbilical and modification of the tubing hanger for the subsea double-contact connectors. In areas where control equipment is scattered on a location, it is preferable to add remote capabilities to such equipment. This will enable quick responses during unexpected events and will also save operators time by avoiding personal and direct supervision on components as in the case of the HPU.

7.2. Results The decision to deploy an intelligent well for water injection reservoir management and the control and optimization of the sweep efficiency is a novel approach of exploiting the value of IWC in deep water developments. The secondary drive for the use of IWC in this application is the possibility of performing fall-off tests without costly well interventions. Petrobras has determined that IWC adds value in applications with wells with more than one production or injection zone; wells with a long horizontal trace and multilateral wells. In these types of wells, the IWC adds even more value when it enables simultaneous control in real time of every pay zone, well leg and horizontal section. 8 Rio Oil & Gas Expo and Conference 2004

The Roncador field was selected among other offshore fields with this intelligent completion because of its strategic importance and the reservoir properties that appear in many zones with similar potential and commercial characteristics. The intelligent injector well makes it possible to return value to Petrobras as an increase in recovery through optimal reservoir sweep, and through reservoir pressure maintenance.

7.3. Future Developments IWC is a fundamental piece of the Petrobras strategy to enhance the productivity of its fields by collecting reservoir information and managing the risk of reservoir uncertainty to improve production planning and management. Other wells in the Roncador field have to be evaluated for the benefit of IWC. The well RO-35 was chosen as a prototype for this kind of technology to assist in the evaluation of IWC for other wells in this field. The ideal candidate wells for IWC applications will be those that have multiple production or injection zones. By overcoming the problem of the distance for Roncador 35, there is the expectation of additional production and injection intelligent completions at similar and longer distances. The installation of the intelligent completion in this well is the seed for the implementation strategy in the giant Petrobras fields that will evolve into "Intelligent Fields". There are plans to develop the current intelligent wells further intelligence.

8. Abbreviations Table 2. Table with abbreviations used in this paper

SDACS: Surface Data Acquisition and Control IV-ICV: Infinitely Variable – Interval Control System. Valve. OPC: OLE for Process Control. PLC: Programmable Logic Controller. OLE: Object Linking and Embedding. HPU: Hydraulic Power Unit. GUI: Graphical User Interface. ROV: Remote Operated Vehicle. CCR: Central Control Room. DSV: Diving Support Vessel LER: Local Equipment Room. FPSO: Floating Production, Storage and Offloading Vessel. TER: Turret Equipment Room. SCM: Subsea Control Module. TUTU: Turret Umbilical Termination Unit. IWC: Intelligent Well Completion. PBR Polished Bore Receptacle TCC: Topside Canister Cabinet

9. References

Bruower, D.R., Jansen J.D., “Dynamic Optimization of Water Flooding with Smart Wells Using Optimal Control Theory”, SPE paper 78278, presented at the SPE 13th European Petroleum Conference. Williamson J., Bouldin B., Purkis D., “An Infinitely Variable Choke for Multi-Zone Intelligent Well Completions”, SPE paper 64280, presented at the 2000 SPE Asia Pacific Oil and Gas Conference and Exhibition.

7. Acknowledgements

We appreciate the collaboration during the project of the following people in Petrobras: Otavio Costa, Leonardo Hauaji, Wagner Destro, Ronaldo Izetti, Jose Luiz Arias, Ricardo Muñoz, Misael Porto, Gesus Padilha, Laurindo Almeida, Gremaro, Flavio Diaz, Sergio Dreyer, Joao Rola, Edmilson Soares and Richard Versteegh. We also thank to Paulo Paulo and Roque Vispo with Kvaerner; Adam Kendall, Luiz Viana, Wanderlei and Alan Nicholson with Diamould; also Torgeir Svenningsen, Herman Bik, Brian Kidd, Gary Brady and Tony Warlow with SBM; also Chad Hightower with BJ; Livar Klingsheim and Karl Oyri with Poseidon; Marcos Germano and Alberto Maia with FMC.

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Figure 5. Intelligent Completion Schematic

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Figure 6. Surface Control System Schematic

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