Canada Oil and Gas Installations Regulations — 60
60 (1) The mooring system for a floating platform shall (a) provide an anchor pattern that keeps all anchor lines, anchor chains and anchors a safe distance from existing pipelines, flow lines and other platforms; (b) provide an anchor pattern that gives clear access to any support vessel intended to be used in operations and that clears lifeboat launching areas; (c) be sufficiently stiff so that the excursions of the platform are within the limits established for the risers in accordance with section 62 under all operating conditions; and (d) be sufficiently strong so that the failure of any anchor line during operations will not lead to major damage. (2) The load factor for tension in the mooring lines of every floating platform, based on a quasi-static analysis, shall be (a) in the operating condition with all lines intact, 3.0; (b) in the operating condition with one line failed, 2.0; (c) in the survival condition with all lines intact, 2.0; (d) in the survival condition with one line failed, if the platform will not threaten another platform used for the exploration or exploitation of subsea resources, l.4; and (e) in the survival condition with one line failed, if the platform may threaten another platform used for the exploration or exploitation of subsea resources, 2.0. (3) The fatigue life of the mooring system of every floating platform shall be equal to at least 15 years. (4) The mooring system of every floating platform that is to remain at the production site or drill site for longer than five years shall be designed so that its components can be inspected and replaced. (5) The design of the mooring system of every floating platform that is intended to remain moored in the survival condition shall be based on an appropriate model test or numerical analysis. (6) Where there is an annual probability of 10 -2 of ice or icebergs being present at the site of a floating platform, the mooring system of the platform shall (a) incorporate a primary quick release system with a remote triggering device and at least one back-up system; and (b) have been demonstrated to be capable of permitting the quick release of the platform from its moorings and risers. (7) Except where the floating platform may threaten another platform used for the exploration or exploitation of subsea resources, the following factors may be taken into account in determining whether a thruster-assisted mooring system using a remote control thruster system complies with subsection (2): (a) if the remote control is manual, (i) zero thrust, for the operating condition, (ii) 70 per cent of the net thrust effect from all except one thruster, for the survival condition, (iii) zero thrust, for one mooring line failed in the operating condition, and (iv) 70 per cent of the net thrust effect from all thrusters, for one mooring line failed in the survival condition; and (b) if the remote control is automatic, (i) the net thrust effect from all except one thruster, for the operating condition, (ii) the net thrust effect from all except one thruster, for the survival condition, (iii) the net thrust from all thrusters, for one mooring line failed in the operating condition, and (iv) the net thrust from all thrusters, for one mooring line failed in the survival condition. (8) Mooring system components on a floating platform that interface with the mooring chain or rope, except the attachment in the chain locker for anchor chain and the steel rope attachment on the drum, shall be designed to withstand the forces due to tension required to break the chain or rope. (9) The mooring system for a floating platform shall be designed to keep the platform on location, under any ice loads to which it may be subjected as determined pursuant to section 45, and the chain or rope shall be able to withstand, without significant damage, the abrasion forces imposed by such loads. (10) The load factors between the estimated anchor holding power in the mooring system of a floating platf