GreatNorthCollective/greatnorth-canada-federal-laws-text huggingface dataset:
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 136
Mechanical equipment 136 (1) An operator must ensure that any mechanical equipment on an installation (a) is designed, selected, located, installed, commissioned, protected, operated, inspected and maintained in accordance with the measures referred to in clauses 9 (2)(b)(v)(E) and 10 (2)(b)(v)(E) that are described in the operator’s safety plan and environmental protection plan, respectively; and (b) can operate safely and reliably under all foreseeable operating conditions, taking into account the manufacturer’s instructions. Design (2) Mechanical equipment must be designed to eliminate hazards to safety or the environment in the following scenarios or, if that is not possible, to mitigate the risks posed by those hazards: (a) loss of containment of hazardous substances; (b) overspeeding and loss of restraint of machinery components with high kinetic energy; (c) extreme surface temperatures of the mechanical equipment; (d) movement of mobile components of the mechanical equipment; (e) loss of control and integrity of the mechanical equipment; (f) ignition of potentially explosive atmospheres in hazardous areas from sparks, flames or excessive heat; and (g) escalation of accidental events. Controls and manual shut-off devices (3) The operator must ensure that controls and manual shut-off devices for mechanical equipment are in a protected and readily accessible location that permits safe operation when an accidental event occurs that renders the equipment inaccessible. Internal combustion engine — operating instructions (4) The operator must ensure that the basic operating instructions for an internal combustion engine provide details of stop, start and emergency procedures and are permanently attached to the engine. Turbines and internal combustion engines (5) The operator must ensure that turbines and internal combustion engines are (a) equipped to prevent unintended ignition; (b) installed so that (i) their supply of combustion air is from a non-hazardous area, and (ii) their exhaust is discharged to a non-hazardous area; and (c) equipped with safety devices — including manual fuel shut-off devices and, unless it would increase safety or environmental risks, automatic fuel shut-off devices — to prevent major damage from overspeeding, high exhaust temperature, high cooling water temperature, low lubricating oil pressure or other foreseeable hazards that could impair the safety of operations. Exception (6) Despite paragraph (5)(c), turbines and internal combustion engines that are critical to emergency response, including emergency generators and fire pumps, need only be equipped with safety devices to prevent major damage from overspeeding. Operation of critical mechanical equipment (7) The operator must ensure that mechanical equipment that is critical to the safety or propulsion of a floating platform will continue to operate safely and reliably at its full rated power under the static and dynamic angles of inclination that are specified in the rules of the classification society that issued the certificate of class required under section 140 .
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 137
ed under subsection (5), must be posted inside its control cab. Crane hooks (8) The operator must ensure that all crane hooks are equipped with spring-loaded latches or other equally effective means of preventing the load from falling off the hook under any operating conditions. Landing or take-off (9) When an aircraft is landing on or taking off from a landing area, it is prohibited to move a crane in the vicinity of the landing area and, if feasible, the person operating the crane must ensure that the crane’s boom is stowed. Lifting device certification (10) The operator must ensure that any materials handling equipment that lifts over 10 tonnes is certified by the certifying authority.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 138
Subsea production system 138 (1) An operator must ensure that a subsea production system is designed, constructed, installed, commissioned, operated, inspected, monitored, tested and maintained in accordance with the measures referred to in clauses 9 (2)(b)(v)(F) and 10 (2)(b)(v)(F) that are described in the operator’s safety plan and environmental protection plan, respectively. Design (2) A subsea production system must be designed so that (a) the system can avoid foreseeable hazards or revert to a safe state when hazards are imminent; (b) the system supports and seals connections to the well, pipelines, other subsea production systems or other installations; (c) in the event of a loss of control or communication, the system will revert to a safe state; (d) the failure of a single component of the system cannot cause or contribute to a major accidental event; (e) barrier elements in each conduit that carries fluids are reliable, have the necessary redundancy and are arranged to (i) prevent uncontrolled flow of well fluids, (ii) minimize the quantity of fluids released from the conduit in the event of unintended release, and (iii) permit testing of the integrity of the barrier elements without increasing safety or environmental risks; (f) subsea equipment can withstand or is protected from any load to which it may be subjected that would result in mechanical damage; (g) production risers can withstand or are protected from all hazards and environmental loads to which they may be subjected, other than icebergs; and (h) the blowout preventer is supported by the system during drilling and the tree and any workover or intervention pressure control equipment are supported by the system after completion. Disconnectable riser (3) The operator must ensure that a riser that is connected to a floating platform that has a disconnectable mooring system or dynamic positioning system is designed to be capable of safely detaching in any foreseeable physical and environmental conditions. Riser disconnect (4) The operator must ensure that, if risers are designed to disconnect in order to avoid foreseeable hazards, riser fluids may be safely displaced by water or isolated. Riser integrity (5) The operator must ensure that, if a riser is disconnected, its integrity is demonstrated through testing once it is reconnected and before it is brought back into service. Control of subsea production system (6) The operator must ensure that a subsea production system is controlled from only one location at any given time. Failure modes and effects analysis (7) The operator must ensure that any subsea production system is assessed through a failure modes and effects analysis.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 139
Temporary or portable equipment 139 (1) An operator must ensure that any temporary or portable equipment used on an installation is fit for the purposes for which it is to be used. Assessment of temporary or portable equipment (2) Before any temporary or portable equipment is installed or brought into service on an installation, the operator must ensure that the equipment and its integration with other equipment and systems are assessed to determine their impact on safety-critical elements and on the risk assessment referred to in subsection 24 (3). Measures (3) The operator must ensure that temporary or portable equipment is managed in accordance with the measures referred to in clauses 9 (2)(b)(v)(G) and 10 (2)(b)(v)(G) that are described in the operator’s safety plan and environmental protection plan, respectively, and in a manner that does not compromise the target levels of safety set out in those plans. Verification by certifying authority (4) The operator must ensure that temporary or portable equipment that is a safety-critical element is, before being put into operation, verified by the certifying authority to confirm its suitability and safe placement and hook-up.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 140
Classification 140 An operator must ensure that a floating platform holds a valid certificate of class issued by a classification society that corresponds to the authorized work or activity to be carried out from the floating platform.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 141
Air gap 141 An operator must ensure that a platform that is either founded on the seabed or column-stabilized has a sufficient air gap to operate safely under the maximum environmental load conditions to which it may be subjected.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 142
Stability 142 (1) An operator must ensure that a floating platform, whether intact or in a damaged condition, is stable and can be operated safely, having regard to all motions and loads to which it may be subjected, including by (a) determining the stability and motion response characteristics of the platform using analysis or model testing; (b) determining the critical maximum loads and motions that the platform can withstand; (c) ensuring that all equipment is fastened to prevent unintended movement; and (d) monitoring and recording all loads that could affect the motions, stability or inclination of the platform. Freeboard (2) The operator must ensure that a floating platform has sufficient freeboard to operate safely under the maximum environmental load conditions to which it may be subjected. Requirement — Codes (3) The operator must comply with the applicable provisions of the MODU Code and Part B of the IS Code concerning the stability and motion response of a floating platform, which are to be read as mandatory. Deadweight survey (4) If the weight of a floating platform or a self-elevating mobile offshore platform changes by more than 1% of the lightship weight, the operator must ensure that a deadweight survey is carried out at the earliest opportunity and an up-to-date value of the lightship centre of gravity is calculated.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 143
Self-elevating mobile offshore platform 143 (1) An operator must, in relation to a self-elevating mobile offshore platform, ensure that a site-specific assessment is conducted of the condition of the seabed, including seabed restraint, to ensure that the platform is stable and can be operated safely. Requirements (2) The operator must ensure that a self-elevating mobile offshore platform meets the following requirements: (a) it must be equipped with systems to actively monitor (i) hull inclination, (ii) leg penetration into the seabed, (iii) loads on each of the platform’s legs, and (iv) rack phase differential, if applicable; and (b) its jacking mechanisms must be designed so that the failure of a single component does not cause an uncontrolled descent of the platform. Suspension of operations and well shut-in (3) The operator must ensure that the works and activities on a self-elevating mobile offshore platform are suspended and that all wells associated with the platform are brought to a safe shut-in condition if (a) hull inclination or the rack phase differential exceeds the allowable limits set out in the operations manual in accordance with paragraph 157 (3)(b); (b) unexplained changes occur in the loads on any of the platform’s legs; (c) leg penetration into the seabed increases; or (d) any other event threatens the stability of the platform. Corrective measures (4) In the case of any of the situations referred to in subsection (3), the operator must ensure that the works and activities on the self-elevating mobile offshore platform remain suspended and that all wells associated with the platform remain in a safe shut-in condition until the cause of the situation has been investigated and corrective measures have been taken.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 144
Ballast and bilge systems 144 (1) An operator must ensure that a floating platform is equipped with reliable ballast and bilge systems with the necessary redundancy in their components to (a) maintain necessary draught, stability and hull strength under all foreseeable operating conditions; (b) return the floating platform to a safe condition from an unintended draught, trim or heel; (c) prevent unintended transfer of fluid within the system; (d) empty and fill all tanks that are a part of the system; and (e) completely and rapidly empty watertight spaces. Requirement — Code (2) The operator must comply with the applicable provisions of the MODU Code concerning ballast and bilge systems, which are to be read as mandatory. Secondary ballast control station (3) In the case of a column-stabilized mobile offshore platform, the operator must ensure that it is equipped with a secondary ballast control station that is equipped with (a) an effective means of communication with other spaces that contain equipment relating to the operation of the ballast system; (b) a ballast pump control and status system; (c) a ballast valve control and status system; (d) a tank level indicating system; (e) a permanently mounted ballast schematic diagram; (f) heel and trim indicators; (g) a draught-indicating system; (h) a system to indicate the available power from the main and emergency electrical power supplies; and (i) a ballast system hydraulic or pneumatic pressure-indicating system. Location — secondary ballast control station (4) The operator must ensure that a secondary ballast control station is located above the waterline in the final condition of equilibrium after flooding if the floating platform is in a damaged condition. Failure modes and effects analysis (5) The operator must ensure that the ballast and bilge systems are assessed through a failure modes and effects analysis before any authorized work or activity is carried out from the floating platform.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 145
Watertight and weathertight integrity and freeboard 145 (1) The operator must comply with the applicable provisions of the MODU Code and Part B of the IS Code concerning watertight and weathertight integrity and freeboard, which are to be read as mandatory. Watertight subdivision (2) The operator must ensure that the floating platform is designed with sufficient watertight subdivision to ensure the preservation of reserve buoyancy and damage stability under all foreseeable conditions. Load line certificate (3) The operator must ensure that a floating platform (a) holds an International Load Line Certificate or an International Load Line Exemption Certificate issued by the government of the state whose flag the platform is entitled to fly, as required under Article 16 of the International Convention on Load Lines, 1966; and (b) is marked in accordance with the certificate. Watertight and weathertight appliances (4) The operator must ensure that the arrangement and specification of watertight and weathertight appliances complies with the measures referred to in clause 9 (2)(b)(v)(H) that are described in the operator’s safety plan. Water ingress (5) The operator must ensure that a floating platform is designed with systems and equipment that provide for the operation, monitoring and indication — both locally and at the ballast control stations — of the opening and closing of watertight doors and hatches and for the detection and provision of alerts of any water ingress into watertight spaces that are not designed to accumulate liquid. Port lights (6) The operator must ensure that the columns of a column-stabilized mobile offshore platform do not have port lights or similar openings.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 146
Station-keeping 146 An operator must ensure that a floating platform is equipped with a mooring system or a dynamic positioning system to ensure station-keeping of the platform within its operating limits.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 147
Mooring system 147 (1) An operator must ensure that a mooring system with which a floating platform is equipped is designed, on the basis of analysis and model testing, to ensure (a) safety and the protection of the environment; (b) the stability and serviceability of the floating platform; (c) the integrity and serviceability of the mooring system components, including any related topside equipment; (d) the integrity and serviceability of drilling risers, production risers, export risers or any other type of riser; (e) the necessary redundancy of the mooring system components to enable the floating platform to maintain its position with the loss of a single component or, for a thruster-assisted mooring system, the loss of the most effective thruster or a single failure in the power or control system; (f) for a thruster-assisted mooring system, the ability of the floating platform to withstand extreme meteorological conditions in the event of a power failure; (g) the ability of the floating platform to move from its position to avoid accidental events that it is not designed to withstand; and (h) safe access and safe clearances with respect to subsea and surface components of the installation, any nearby installations, support vessels and evacuation systems. Excursion limits (2) The operator must ensure that the excursion limits of a floating platform that is equipped with a mooring system are established on the basis of the analysis and model testing referred to in subsection (1). Loss of station-keeping or failure (3) The operator must ensure that the floating platform has systems and processes to continuously detect loss of station-keeping or the failure of any mooring system component. Monitoring (4) The operator must ensure that mooring line tensions or other indicators of the integrity of the mooring system are monitored and kept within the mooring system’s operating limits. Measures (5) The operator must ensure that measures to ensure that the mooring system continues to perform in accordance with its design specifications are implemented, including (a) the assessment of the system’s condition, periodically and if it is damaged or if damage to it is suspected; and (b) the making of arrangements for timely repair or replacement in the event of damage or deterioration.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 148
Disconnectable mooring system 148 (1) If the mooring system with which a floating platform is equipped is disconnectable, the operator must ensure that the system is designed to ensure that disconnection can be accomplished in a controlled manner without creating a risk of drift-off. Safety plan (2) The operator must ensure that the disconnectable mooring system is designed and maintained in accordance with the measures referred to in clause 9 (2)(b)(vi)(D) that are described in the operator’s safety plan. Primary and backup systems (3) The operator must ensure that the disconnectable mooring system includes a primary system and a backup system for disconnection, both of which can be operated locally or from a remote location. Floating platform capability (4) The operator must ensure that a floating platform that is equipped with a disconnectable mooring system is capable of (a) safely manoeuvering away under its own power; and (b) maintaining a safe position and heading while disconnected. Criteria and procedures for disconnection (5) The operator must ensure that criteria and procedures for disconnection are developed for all credible disconnection scenarios, including procedures for monitoring environmental conditions and providing alerts for worsening conditions that may require disconnection. Disconnection and reconnection (6) The operator must ensure that the disconnectable mooring system (a) is capable of carrying out a planned disconnection after allowing time for the depressurization and flushing of subsea flowlines; (b) is capable of carrying out an emergency disconnection after allowing time to safely shut in wells and subsea equipment; (c) allows for the reconnection to the floating platform of the system and flowlines in an orderly sequence, in the physical and environmental conditions described in the operations manual under paragraph 157 (2)(c); and (d) allows for the resumption of production after the system and flowlines have been reconnected to the floating platform following a planned disconnection; Periodic verification of disconnection capability (7) The operator must periodically verify the disconnect capability of the disconnectable mooring system and must record the findings resulting from the verification. Excursion limits exceeded (8) The operator must ensure that the emergency disconnection referred to in paragraph (6)(b) is initiated if the floating platform exceeds the excursion limits established under subsection 147 (2).
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 149
Dynamic positioning system 149 (1) An operator must ensure that the design of a dynamic positioning system with which a floating platform is equipped (a) is based on numerical analysis and model testing to ensure that the floating platform’s position reference and directional control can be maintained within specified tolerances that satisfy design operational requirements in relation to all functional and environmental loads to which the system may be subjected at the floating platform’s intended location; (b) is based on a failure modes and effects analysis to ensure the segregation and redundancy of safety-critical systems and their components as necessary to maintain the platform’s position in the event that credible scenarios of equipment failure are realized; (c) allows the dynamic positioning system to withstand the loss from fire or flooding of all of its components situated in any one watertight compartment or fire subdivision of the floating platform; and (d) includes systems to monitor the parameters of operability and integrity of the critical systems of the dynamic positioning system and to provide alerts for critical system faults. Excursion limits (2) The operator must ensure that the excursion limits of a floating platform that is equipped with a dynamic positioning system are established based on the numerical analysis and model testing referred to in paragraph (1)(a).
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 150
Disconnect system 150 (1) An operator must ensure that a floating platform that is equipped with a dynamic positioning system has a disconnect system that (a) is capable of carrying out a planned disconnection of the floating platform from the seabed after allowing time to prepare the risers and subsea flowlines for the disconnection; (b) is capable of carrying out an emergency disconnection after allowing time to safely shut in wells and subsea equipment; and (c) allows for reconnection in an orderly sequence, in the physical and environmental conditions described in the operations manual under paragraph 157 (2)(c). Demonstration (2) The operator must periodically demonstrate by means of a trial or performance test that the disconnect system meets the requirements under subsection (1). Excursion limits exceeded (3) The operator must ensure that the emergency disconnection referred to in paragraph (1)(b) is initiated if the floating platform exceeds the excursion limits established under subsection 149 (2).
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 151
Decisions and exemptions 151 For any floating platform that is registered outside Canada, the operator must (a) establish a list of all flag State administration decisions and exemptions that apply to the floating platform in relation to any standards adopted by the International Maritime Organization; (b) conduct a risk assessment to identify measures to reduce the safety and environmental risks in relation to those decisions and exemptions to a level that is as low as reasonably practicable; and (c) establish an action plan to implement the measures referred to in paragraph (b).