The following specifications apply to all users of the Triton FPSO and to all produced fluids which are within the relevant design specification parameters of the joint facilities and which can be processed by the Triton FPSO facilities such that:
- any resulting gas meets the re-delivery specification for gas;
- any resulting dry oil can be delivered to the dry oil redelivery point and does not adversely affect the value of existing dry oil production; and
- it does not adversely affect the Triton FPSO facilities capacity.
The relevant design specification parameters of the Joint Facilities are:
Flow-rates and Metering:
This is dependent upon the capacity of the plant and the spare risers, and the gas to oil ratio (GOR) of the field production streams. Slugging into the joint facilities is to be minimised and no liquid slug is to exceed 15 cubic metres for the Bittern Field Flowline System and 10 cubic metres for the Guillemot West Flowline System.
The maximum separator off-gas molecular weight should be in the order of 22 to 25.
Maximum FPSO arrival temperature is 50° Celsius. Minimum normal arrival temperature is 30° Celsius.
The minimum delivery pressure is 20 barg at the riser top. Maximum shut-in pressure to be advised and the sub-sea system is to be designed for this pressure. Joint facilities are designed for 179 barg. In-field pipeline settle-out pressure to be advised to the Triton Operator.
Petroleum produced from any field shall not contain emulsions which cannot be destabilised by heating to 70° Celsius and the application of electrostatic coalescence. Any chemical demulsifiers required must be compatible with those already in use.
Produced water from the fields is not to contain levels of Strontium or Barium ions which may cause precipitation of scales if commingled with sea water or other formation water present. The total dissolved solids is not to exceed 75,000 milligrams per litre.
The absolute viscosity of the stabilised crude, is not to exceed 3.5 centipoise at 40° Celsius or 2.5 centipoise at 50° Celsius. Any non-Newtonian behaviour is to be notified to the Triton Operator.
Wax Content and Appearance point:
The wax appearance point temperature is not to be greater than 35° Celsius. The wax content and the nature of its precipitation are to be notified to the Triton Operator. The Field Operator shall advise the Triton Operator of the need and operating policy for avoiding wax build-up in the sub-sea system.
The gravity of the stabilised crude oil shall be in the order of 28° to 40° API.
The solid content of the field production stream is not to exceed 6 lbs per thousand barrels.
Petroleum must exhibit a low foaming tendency when processed alone and when mixed with existing field production streams in the joint facilities.
Asphaltenes are not to precipitate in processing equipment or storage tanks when processed alone, or when mixed with existing field production streams in the joint facilities.
Petroleum salt content shall not exceed 25lbs per thousand barrels at a BS&W of 0.1%.
Field petroleum shall not contain more than 3.0 ppm volume of hydrogen sulphide at first stage separator conditions.
Field petroleum shall contain no detectable mercaptans at first stage separator conditions.
Field petroleum shall contain no detectable carbon disulphide at first stage separator conditions.
Field petroleum shall not contain more than 13.5 ppm volume total sulphur measured as hydrogen sulphide at first stage separator conditions.
Field petroleum shall not contain more than 2. 7 mole % of carbon dioxide at first stage separator conditions.
Aggregate total of non-hydrocarbon content of first stage separator gas shall not exceed 5.0-mole%.
Field petroleum shall not contain more than 0.01 micrograms of mercury per m3 of gas at first stage separator conditions.