System Description The Foinaven riser and umbilical system comprises of 10 flexible pipes and 2 umbilical and provides production, test, gas injection, water injection and control for two drilling centre. The size and duty of the risers is as follows:- Drill Centre I 2 × 10" Production 2 × 8" Production/Test 1 × 10" Water Injection 1 × 8" Gas Injection I × Dynamic Umbilical Drill Centre 2 2 × 10" Production 2 × 8" Production/Test I × Dynamic Umbilical The design pressure for the system is 3689 psi (254 bar g). The configuration of the risers is a "pliant wave" (figure I) which is anchored to a gravity base structure by tethers and has buoyancy modules distributed along the lower end. The system is designed such that it can be released from the FPSO in extreme emergency conditions. Design Conditions The Foinaven field is the deepest ever application of a "pliant wave" riser configuration and has to withstand very high currents over the full water column of up to 2 m/s (3.9 knots), When combined with the 100 year design wave of 18 m (sign) this provided very harsh conditions for the design of the pipe (figure 2), the critical areas being the vessel interface, where a bend stiffener is required, and at the riser touchdown point where extreme near and far vessel positions resulted in the need for a hold back anchor to prevent pipe movement and subsequent over bending of the pipe. The large waves in the Atlantic also impose severe fatigue loading on the risers, the most critical risers being the gas and water injection risers, due to the high operating pressure within the system. Next to the environmental conditions the next major influence on the system design was the vessel offset. This is closely linked to the design of the mooring system for the vessel which was far more compliant than originally anticipated in the riser design. When procuring a floating production system the risers influence both the sub sea layout as well as the mooring system design. Care must therefore be taken in addressing this interface. If the interface is defined at the riser touchdown the cost benefit of manufacturing flexible flow line jumpers (especially the flow line to manifold jumpers) at the same time as the riser maybe lost. Also for the umbilical, vessel interface was one of the major challenges. The region that experiences the highest loads both with respect to tension and bending is found at the I-tube exist. Bend stiffener design as well as cross-section design is critical. At touch down two clump weights were needed, One main clump weight taking up virtually all the tension, leading to that the touch down area saw no tension at high bending. the resulting catenary below the tether clamp, however, induced such a high bottom tension in the extreme current and far vessel offset cases that the interface joint between dynamic and static umbilical was anchored to a second, smaller slump weight. Its role is to prevent axial movement of the interface joint thereby preventing potential unwanted configuration changes.

Summary. The flexible riser and mooring system (FRAMS) provides a technically straightforward, commercially attractive method of developing small on fields. A passively moored 60,000-deadweight-ton (60,000-DWT) tanker with deck-mounted equipment provides a swivelless well fluid and injection water path from and to the wellheads. The system can be disconnected rapidly in severe weather. Introduction In a typical FRAMS field development, a small North Sea oil field would be developed by a moored 60,000-DWT tanker restrained against environmental forces by a 5-in. diameter spiral-strand wire to an anchor base by means of a midwater buoy. Three 5-in. OD flexible pipes would be held off the wire with spiders: one that conveys well fluid, one that transports injection water, and one that is an electrohydraulic umbilical cable. The tanker would be free to rotate about the mooring, using the inherent flexibility of the lower riser hoses, up to a design limit of 300 deg. rotation. The mooring would act as an inverted pendulum being displaced when environmental forces cause the tanker to move or to weathervane. The mooring would provide a restoring force to the tanker. (See Fig.1 for an overview of the FRAMS concept.) Experience shows that a field suitable for development by FRAMS would be one in the central North Sea with an oil reservoir of 10 to 20 million bbl, recoverable over 5 years with up to five wells. The GOR should not exceed 500, and the water depth should be at least 260 ft. This paper outlines the sequence of activities through conceptual design, analytical work, model testing, and voyage simulation. This work supports the hypothesis that a buoy/tanker system can be engineered to provide an attractive method of developing small oil fields. provide an attractive method of developing small oil fields. Design Philosophy The overall design aim was to reduce capital and operating costs by simplifying the design requirements and using straightforward engineering. Consequently, fluid swivels and dynamic and active positioning are avoided. Because no provision is made for the ship to remain connected to the mooring in all weather, the need to size components for the most severe conditions is avoided. A 5-year-old tanker would be converted and equipped with above-deck, palletized units and would use its attendant anchor handler as an occasional tug. The tanker would return to port to discharge its cargo, providing opportunities for inspection and dry-docking if needed. Preliminary Design Preliminary Design Analytical work was carried out with the AQWA suite of programs to determine the sizes of the mooring components for a typical base-case field. A detailed diffraction wave-loading analysis was performed with a 60,000-DWT tanker hull for 4 wave directions and 10 wave periods. Loading coefficients for wind, current, yaw, and mooring drag were calculated. This analysis provided top- and bottom-line loadings. A personal computer model was set up to simulate a mooring system's restoring forces for different buoy displacements, bottom-and top-line lengths, and tanker offsets. As in almost all design work, a had to be reached to satisfy conflicting ideal values. The final configuration of a 200-tonne buoy and top- and bottom-and lengths of 490 and 330 ft, respectively, was selected. The choice of a relatively long top-line length is supported by North Sea experience on tanker off-take loading operations. The longer length reduces the possibility of snatch loads and increases the fatigue life of the mooring. possibility of snatch loads and increases the fatigue life of the mooring. The loadings in the mooring led to the use of a 5-in.-diameter spiral-strand wire rope, giving a safety factor of at least four for the bottom line and eight for the top line. The analysis confirmed that the tanker stayed mainly in a 90 quadrant. On the basis of the manufacturer's limit of 0.33/ft acceptable torsion, the mooring system was felt to be capable of operating with enough uptime for adequate production performance. Topsides Design The process and utility facilities installed on the FRAMS tanker were designed specifically for a typical central North Sea field. Table 1 gives the characteristics of this reservoir. The topsides equipment was selected and sized in accordance with conventional principles. For oil production, a single train of three-stage separation was specified and sized for a nominal production of 10,000 B/D of total fluids with provision for produced-water facilities. No test separator was provided, so well testing would be done by shutting in the other wells. The water-injection equipment was sized for 120 % of the specified rate to allow for downtime and an increase in the injection rate. Additional power generation would be installed to take advantage of produced-gas availability. Two dual-fuel (diesel/gas) engines were proposed; two gas turbines may be used as an alternative. The flare tower, proposed; two gas turbines may be used as an alternative. The flare tower, which is 80 ft in front of the facilities, is rated to bum all produced gas (3 MMscf/D). The skid-mounted process and utility facilities are located near midships on the tanker. Hazardous equipment is separated from nonhazardous equipment. A weatherproof, mechanically ventilated control cabin would house subsea controls; process controls; and fire, gas, and emergency shutdown systems. The cabin, located in a safe area, is staffed continuously. Subsea and Downhole The major subsea elements of the base development include two producer wells and one water-injection well in a tight cluster (around a manifold structure), two parallel flowlines about 0.5 mile to the mooring base, a valve control system, and chemical-injection equipment fed by the umbilical line from the FRAMS tanker. Standard wellheads are used for both production and injection wells. production and injection wells. Well stream from the production wells is combined into a single flowline. Because the operating procedure calls for produced oil to be flushed from the flowline and header while the tanker is off-station, crossover pipework is provided in the manifold. A multiplexed electrohydraulic control system was selected for FRAMS. In normal operation, the system is largely conventional. While the tanker is off-station, the hydraulic pressure is locked in and electric power maintained by rechargeable subsea batteries on the manifold. Use of an acoustic control system was considered. This system offers the advantage of maintaining full control and status monitoring of the subsea equipment while the tanker is disconnected-for example, during a mooting unwind operation. It also offers improved operational life of the downhole safety valves. Downhole equipment was designed on the basis of a recent BP Exploration subsea field development tied back to a nearby host platform. Trees can be changed without heavy workover. For cost purposes, 13 % chrome production tubing has been allowed for because one of the candidate fields may require this. Copyright 1991 Society of Petroleum Engineers P. 465

The Flexible Riser and Mooring System (FRAMS) provides a technically feasible and commercially attractive method of unlocking small U. K. North Sea oil fields. A moored 60,000 OWT oil tanker, fitted with deck mounted production equipment is restrained by a mid-water bu::>y, while the swivel-less riser bundle conveys well fluid from, and injection water to, the subsea wellheads. In severe weather, oil production is stopped, and the tanker disconnects from the mooring, re-connecting when weather allows.