Today's demands relating to environmental discharges puts great demands on the operators in the oil industry.

For example, some of the operators stipulate that there shall not be any discharge of drilling fluid during drilling. During drilling of a new oil well in the ocean bed, or drilling in an already existing well, large amounts of drilling fluid, which must be treated, are produced.

This can be oil-based drilling fluid or water-based drilling fluid, depending on whether the drilling which is being carried out, is top-hole drilling or drilling in the oil zones.

In this application, drilling fluid is meant to be fluids which appear during drilling in a drilling hole, such as cuttings, drilling mud, or other drilling fluids.

In recent years, the environmental threats which the oil industry poses, have been given increasingly more focus. The authorities have imposed increasingly stronger demands on care for the environment and have strict rules

for discharges from offshore installations, as these can have negative effects on the maritime environment. Today, there are, in the main, strict restrictions with regard to discharges of oil-based drilling mud, and discharges of this type have almost been completely stopped in the Norwegian sector of the North Sea.

In a standard well, in which the following holes are drilled without risers (36"-225m. 26"-1200m), more than 340 m3 of cuttings will be produced directly from the well.

In addition there is the drilling mud with its mixture of different chemicals. The Norwegian Pollution Control Authority (SFT) introduced a complete ban on dumping of drilling mud and/or drilling fluid in the Norwegian sector of the North Sea in 1993. This was the start of what is today called slurry-fixing plants, which are able to process the return of fluid to the drilling hole.

Today, most of the fixed installations have such plants, but they are only used for injection of oil- containing waste. The injection is carried out in an annular space between two casings in the drilling hole, normally casings with diameters of around 340 mm and 508 mm (13 3/8"and 20"). This is based on a pump rate of about 4000 1/min under drilling of about a 311 mm (12 1/2") section and about a 216 mm (8 1/2") section.

Water-based drilling fluids are discharged directly to the sea and sink to the ocean bottom, something that creates environmental problems for the maritime life both in the ocean and at the ocean bottom. Discharges of drilling fluids can be carried out with the aid of a pump which is connected on a base at the drilling hole. The pump acts as a suction pump to create a negative pressure in a sealing device which is arranged round the drill column in the drilling hole.

Disadvantages with today's methods are that if the water-based drilling fluid is to be transported up to the drilling rig to be injected into a corresponding well, many problems to which there are no solutions at present arise.

For example, during top-hole drilling there are no maritime

risers, i. e. a vertical riser which transports drilling mud from the ocean bottom and up to the drilling platform, and in addition there is no annular space for injection of the water-based drilling fluid.

There is, therefore, a need for a method that can remove discharges of drilling fluid returns at a drilling rig or drilling vessel, and which can be applied in connection with the already existing drilling hole applications both on the ocean bottom and on the drilling rig. There is also a need for a system to carry out the method according to the present invention.

Advantages with the method according to the present invention are that great savings are achieved by being able to recirculate drilling fluid returns. Full drilling rate is maintained in the different sections, i. e. about 311 mm and about 216 mm (12 3/4"and 8 1/2") sections. Moreover, the environment is spared from unnecessary discharges. A faster slurrification of the drilling fluid which is produced during drilling, is also achieved, i. e. faster treatment of the pumpable fluid or mud which consists of a solid material sedimented in a fluid. Less strict demands for the slurry. No wearing of casings will occur, and there is no danger that the casing will be damaged. Drilling fluid is kept away from the template, i. e. the base, and no concrete is used around the template. This gives a clear view for the ROV operator (Remotely Operated Vehicle). A greater injection rate is also achieved. In addition, the drilling fluid can also be stored for later, to be transported away from the floating drilling rig.

In connection with drilling on the ocean bed, drilling fluid is formed around the drilling mould (template). It is normal to use remote controlled underwater vehicles (ROV- "remote operated vehicle") with a camera, to monitor and carry out various operations, and the drilling fluid/mud in the area around the drilling hole orifice represents, therefore, a considerable visual problem. Cuttings are fragments of rocks, which under drilling are brought up with the drilling mud.

The object of the present invention is, therefore, to provide a method and a system, which eliminates the abovementioned problems. It is also an object to provide a method and a system of processing drilling fluid return from a drilling hole in an underwater well at a floating drilling rig or a drilling vessel, comprising a sealing device connected to a well head, and a pump module to transport drilling fluid, a treatment plant, or a storage installation, for drilling fluid and possibly an injection pump.

The method, according to the present invention, is characterised in that before a blow-out valve is mounted on the well head and before risers are connected between the drilling hole and the drilling rig or drilling vessel, drilling fluid is being transported from a drilling hole on the ocean bed by a bottom pump module, which is connected to a sealing device, via a return pipe, to a treatment plant or storage installation on the floating drilling rig or drilling vessel.

The system, according to the present invention, is characterised in that a pump module, which is arranged on the ocean bed and connected to a sealing device, is adapted to transport drilling fluid from the drilling hole on the ocean bed, via a return line, to a treatment plant, or a storage installation, on the floating drilling rig or drilling vessel.

Preferred embodiments of the method, according to the present invention, are specified in that the pump module placed on the ocean bed and the sealing device provides an outlet pressure, dependent on the weight of the mud and ocean depth, which is high enough to transport drilling fluid from the drilling hole, through the return line and up to the floating drilling rig or drilling vessel. The drilling fluid is transported through the return line and to the existing line (flow-line) on the floating drilling rig or drilling vessel for further transport to the treatment plant or storage installation. After the cuttings is treated, using a method that may be known previously, on

the floating drilling rig or drilling vessel, the treated cuttings is injected, with the aid of a high-pressure pump, into a second drilling hole provided on the ocean bed, or in an adapted annular space in the first drilling hole.

Preferred embodiments of the system are characterised in that the pump module placed on the ocean bed is connected to the sealing device and together form a suction and centralisation module, arranged at the well head, and which is adapted to provide an outlet pressure which is high enough to lift the drilling fluid from the drilling hole through a return line and to an existing line (flow- line) on the floating drilling rig or the drilling vessel.

The pump module placed on the ocean bed comprises a number of pumps to provide the necessary pressure, such as a centrifuge and/or a friction pump possibly connected in series, where the pump, or pumps, are driven by a submerged electric motor which is connected to the pump or pumps.

A prefered embodiment, according to the present invention, shall now be described with reference to the enclosed figures. It must be understood that this example is not limiting and that other and further modifications may be carried out within the scope of the claims.

Figure 1 shows a principle of the method and the system for processing of a drilling fluid according to the present invention.

Figure 2 shows a section of an injection well according to figure 1.

To a first drilling hole 10 which is already drilled in the ocean bed, it is common to connect a sealing device 12, which normally is described as a suction and centralisation module (SCM), as shown in figure 1. This sealing device 12 is connected to the well head of the first drilling hole 10, for example, to form a seal between the foundation at the well head and a pipe string up to the drilling rig, and to create a negative pressure in the drilling hole for suction of drilling fluid.

The present invention applies, amongst other things, such a known system, with a sealing device for removal of

drilling fluid from a drilling hole orifice, which is characterised in that between the inner surface of the casing and outer surface of the drilling column an end- piece which forms a seal, basically a watertight seal, is arranged between the casing and the drilling column, and that at least one exit passage is arranged in the casing which is connected directly to a line system whereupon a pump module, for example, can be connected. This system is based on the applicant's Norwegian patent application no.

19982394.

A pump module 14 is connected to this exit passage or outlet on the sealing device 12 for suction of drilling fluid/drilling mud. The outlet pressure is dependent on weight of mud and water depth. For example, at a water depth of 400 m and a mud weight of 1.7, the pressure will be approximately 22 bars. Because of the negative pressure in the well head 10 generated by the sealing device 12 and the pump module 14, a lifting height, including pressure drop and lifting reduction because of the weight of the slurry, is generated, sufficient to lift the drilling fluid up to an existing line on the drilling rig, for example an already existing"flow line", which is well known to those skilled in the art. Transport of the drilling fluid from the pump module 14 to the existing line can, for example, be carried out in a about 152 mm (6") or 203 mm (8") pipe/line 16 which is connected to the already existing line (flow line) on the drilling rig. The pipe 16 must be of a type which can withstand the working-pressure which is necessary to lift the slurry up to the floating drilling rig or drilling vessel.

The pump module comprises a pump of known type which can pump seawater, drilling fluid and cuttings under high pressure. At greater depths, it may be necessary with a multi-step solution, for example, two or more pumps connected in series, to obtain the required pressure. The pump is arranged as a module which can be tested and thereafter lowered down to the ocean bed ready for use after pipes have been connected to the inlet and outlet. To

reduce the weight and dimensions, it seems sensible to use a centrifugal and/or friction pump driven by a submerged electric motor, which is connected directly to the pump.

The power supply can be arranged in a compounded umbilical cord (umbilical), which can also be used to lower the pump down to the ocean bed.

After transport of the drilling fluid to the floating drilling platform or drilling vessel, the drilling fluid is thereafter led to a treatment plant, or alternatively, a storage installation on the floating drilling rig or drilling vessel for further transport to another treatment plant or storage installation.

The treatment plant on the floating drilling rig or drilling vessel comprises, for example, a shaking unit (shaker), a first storage tank, a mixing tank, a crushing unit, other storage tanks, and a high-pressure injection pump, etc.

The water-based drilling mud is strained in the shaking unit. Extra seawater is strained and returned to a storage tank, for mixing of slurry for injection. When this method is used, approximately 80 to 90 % of the water-based drilling mud can be recirculated. This gives very large cost savings per day during, for example, top-hole drilling. After the drilling fluid has been strained in the shaking unit, it is transported to a tank which comprises a number of crushing units or crushing pumps. The slurry is crushed in the crushing units or crushing pumps to a preferred particle size of around 10 to 20u, or another suitable size, whereupon the matter is pumped to a storage tank before it is transferred to an injection unit, such as for example a high-pressure pump, for injection into a second drilling hole 18. This injection can, for example, be carried out in a 102 mm (4") injection tube 20 with a working pressure of between approximately 35-150 bars.

The method, according to the present invention, can also include that an injection well is drilled at a distance from the first drilling hole 10. An example of a new injection well is shown in figure 2, and can, for

example, be a well 18 which is drilled for placing of a 178 mm (7") casing 22 in a 340 mm (13 3/8") casing 24, with, for example, a well depth of approximately 500 to 1500 m.

This well depth can also vary, depending on the formation which is being drilled, and how receptive the formation is to the drilling fluid which is to be injected. An area 26 of the lower part of the inner casing is perforated for injection of the water-based drilling fluid.

Injection of the drilling fluid can also be performed in the first drilling hole (10), in a suitable annular space which may be between the casing and formation.

The drilling fluid, which is stored in the storage tank on the drilling rig, is injected with by the high- pressure pump, and through a wellhead system which is connected onto the well. This wellhead system can be of a type which, for example, gives a wear-free injection and which also increases the capacity of the injection.

In principle, the treatment plant can be placed at an arbitrary place as long as the drilling fluid can be pumped to the treatment plant and the drilling fluid can be injected into the second drilling hole. In the first example conducted, the treatment plant is placed on the drilling rig, because the already existing treatment plant is normally installed there, but the treatment plant for the drilling fluid can, off course, be placed somewhere else.

Thus, a new method and system for transport drilling fluid from a drilling hole on the ocean bed to a floating drilling rig or drilling vessel is provided, improving the environment in the sea.