GreatNorthCollective/greatnorth-canada-federal-laws-text huggingface dataset:
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 126
he mechanically driven generator has redundancy in its starting capabilities and a dedicated fuel source. Design and maintenance (3) The operator must ensure that the emergency electrical power supply together with any transitional source of electrical power and self-contained battery system with which the installation may be equipped are designed and maintained such that (a) they are able to provide the systems and equipment referred to in subsection (1) with an emergency power supply of sufficient capacity, taking into account starting currents and the transitory nature of electrical loads, and sufficient duration to ensure that the systems and equipment can function as intended and to allow for effective management of the installation during an emergency, including (i) to allow for the complete shutdown and evacuation of the installation, (ii) to facilitate emergency response and the safe escape, refuge and evacuation of persons or to maintain the integrity of the installation, (iii) to ensure sufficient power so that systems that must operate simultaneously can do so, (iv) in the case of a floating platform, to maintain the flotation and stability of the platform, and (v) to bring a well to a safe state and to maintain it in that state; (b) their capacity to provide power to essential systems is not compromised during their maintenance; (c) they have sufficient redundancy to ensure their reliability and, as far as is practicable, to ensure their functional and physical independence from other essential systems or, if that is not practicable, they are arranged so as not to adversely affect or be adversely affected by the operation of those systems; and (d) they are readily accessible. Protection from damage (4) The operator must ensure that the emergency electrical power supply, transitional source of electrical power and self-contained battery system referred to in subsection (3) are arranged — or are otherwise protected from mechanical damage and damage caused by fire, explosion and physical and environmental conditions to which they may be exposed — so that they remain capable of fulfilling their intended functions under all foreseeable operating conditions, including, in the case of a floating platform, under the static and dynamic angles of inclination referred to in subsection 136 (7). Alert (5) The operator must ensure that, in the event of a failure of the main electrical power supply, all control centres are alerted by means of an audible and visual signal that the installation is being powered by the emergency electrical power supply.
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 127
Lights and sound-signalling appliances 127 An operator must ensure that an installation is equipped with the lights and sound-signalling appliances that are required by the Collision Regulations as if that installation were a Canadian vessel to which those Regulations apply, unless compliance with the height and distance requirements of those Regulations is not possible, in which case the lights and appliances must be installed to maximize their audible and visual alerting capabilities for collision avoidance.
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 128
Radar 128 An operator must ensure that an installation other than an unattended installation is equipped with radar for identifying hazards in proximity to the installation and that the radar is continuously monitored.
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 129
Communication system 129 (1) An operator must ensure that an installation is equipped with a communication system that has built-in redundancy and is capable of communicating continuously, including in an emergency, with (a) external emergency response teams; (b) all persons, individually or collectively, at an operations site; (c) all persons who are in transit to or from an operations site; (d) all support craft; (e) all onshore support centres; (f) nearby vessels and aircraft; and (g) nearby installations. Radiocommunication system (2) An operator must ensure that an installation other than an unattended installation is equipped with a radiocommunication system in respect of which the following requirements are met: (a) the system must comply with Part 2 of the Navigation Safety Regulations, 2020 as if the installation were a Canadian vessel to which those Regulations apply; (b) a technical acceptance certificate must have been issued in respect of the system under the Radiocommunication Act ; and (c) a continuous listening watch and radio log must be maintained. Radiocommunication system — unattended installation (3) An operator must ensure that any radiocommunication system on an unattended installation meets the requirements referred to in paragraphs (2)(a) and (b).
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 130
General alarm system 130 (1) An operator must ensure that an installation is equipped with a general alarm system that is capable of alerting persons on the installation of any hazards to safety or the environment other than fire or gas. Additional requirements (2) The operator must ensure that the general alarm system is (a) operational at all times other than when the system is being inspected, maintained or repaired; (b) flagged as being subject to inspection, maintenance or repair, as required; and (c) designed to prevent tampering. Alternative means of alert (3) If a general alarm system is being inspected, maintained or repaired, the operator must ensure that there is an alternative means of alerting persons of the hazards referred to in subsection (1).
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 131
Gas release system 131 (1) An operator must ensure that an installation that includes process tanks, process vessels and piping is equipped with a gas release system that has a flaring system, a pressure relief system, a depressurizing system or a cold vent system. Risk assessment — design (2) The operator must ensure that the design of the gas release system is based on the results of the risk assessment conducted under subsection 107 (1). Design (3) The operator must ensure that the gas release system is designed to (a) release gas and combustible liquid from an installation in a controlled manner without creating a hazard to safety; (b) reduce pressure in the entire process system as quickly as possible while ensuring a safe and controlled release of pressure; (c) minimize the effect on the environment; (d) be activated from the main control centre and from control stations that meet the requirements set out in subsection (5); and (e) ensure that oxygen cannot enter the system during normal operations. Location — system (4) The operator must ensure that the gas release system is designed and located taking into account factors, including physical and environmental conditions, that affect the safe and normal flaring or emergency release of combustible liquid, gases or vapours so that when the system is in operation it does not damage the installation — or any other installation, vessel or support craft in proximity to it — or injure any person. Control stations (5) The operator must ensure that the control stations from which the gas release system is activated are located and spaced so that they remain protected and accessible for safe operation of the system. Flaring systems (6) The operator must, in respect of any flaring system, ensure that (a) if an unlit release of gas could produce toxic gas concentrations or gas concentrations of more than 50% of the lower explosive limit of the released gas, (i) the system has an automatic igniter system that has redundancy in its ignition capabilities, and (ii) in the case of an open flare system, the system and any associated equipment are designed to ensure a continuous flame; and (b) the system and any associated equipment are designed to (i) withstand the radiated heat at the maximum flaring rate, (ii) prevent flashback, and (iii) withstand all loads to which they may be subjected. Risk minimization — vents (7) The operator must ensure that any vent that is used to release gas into the atmosphere without combustion is designed and located in accordance with the measures referred to in clause 9 (2)(b)(vi)(A) and subparagraph 10 (2)(b)(vi) that are described in the operator’s safety plan and environmental protection plan, respectively. Liquid removal (8) The operator must ensure that any liquid, other than water, that cannot be safely and reliably burned at the flare tip of a gas release system is removed from the gas before it enters the flare.
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 132
maintenance activities must not impair the system beyond what is necessary to undertake those activities and must not impede its functioning. Work permit (7) A work permit is required for the testing and maintenance of the fire and gas detection system. Management of override effects (8) The work permit must set out measures to be taken to manage the effects of overriding the fire and gas detection system. Leak repair (9) The operator must ensure that any leak of gas that is detected by the fire and gas detection system or by means of an auditory, olfactory or visual method — including the observation of the dripping of hydrocarbon liquids from an equipment component — is repaired (a) immediately, if the repair is necessary for the purposes of safety or the conservation of petroleum resources; or (b) as soon as the circumstances permit, in any other case.
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 133
e applied for the shortest amount of time possible and with as few as possible being applied simultaneously; and (b) the testing and maintenance activities must not impair the system beyond what is necessary to undertake those activities and must not impede the system’s functioning. Work permit (7) A work permit is required for the testing and maintenance of the emergency shutdown system. Management of override effects (8) The work permit must set out the measures to be taken to manage the effects of overriding the emergency shutdown system. Closure — subsurface safety valve (9) In the case of a production installation, the operator must ensure that, if the emergency shutdown system is activated, any subsurface safety valve closes not later than two minutes after the tree safety valve has closed unless a longer delay is justified by the mechanical or production characteristics of the well.
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 135
 the authorized inspector who conducted the inspection or who conducted or directed the test stating that the boiler or pressure system is fit for the purposes for which it is to be used, (vi) any recommendations regarding the need for modifications to the maintenance program established under section 159 , and (vii) any other observation relevant to safety; and (f) a description of each repair or modification made to the boiler or pressure system. Marking (13) The operator must ensure that a boiler or pressure system is marked with any information that is necessary for its safe installation and operation, including an identifier that permits reference to the documents and records referred to in subsection (6) and the information referred to in paragraphs (12)(e) and (f). Verification (14) The operator must ensure that all operating procedures developed in accordance with subsection (9) and the register referred to in subsection (12) are periodically verified by the certifying authority. Non-application (15) This section does not apply to any of the following: (a) a heating boiler that has a heating surface of 3 m 2 or less; (b) a pressure system that is installed for use at a pressure of one atmosphere of pressure or less; (c) a pressure vessel that (i) has a capacity of 40 L or less, or (ii) has an internal diameter of (A) 152 mm or less, or (B) more than 152 mm but not more than 610 mm if the pressure vessel is used for the storage of hot water or is connected to a water pumping system containing compressed air that serves as a cushion; (d) a refrigeration plant that has a refrigeration capacity of 18 kW or less; or (e) a domestic water and plumbing system.
Canada–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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.