GreatNorthCollective/greatnorth-canada-federal-laws-text huggingface dataset:
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 75
Allocation of group production 75 An operator must ensure that group production of oil, gas and water from wells and the volume of fluids injected into those wells are allocated on a pro rata basis using the flow system, flow calculation procedure and flow allocation procedure approved under subsection 14 (2).
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 76
Allocation over multiple pools or zones 76 (1) If a well is completed over multiple pools or zones, the operator must ensure that the production of oil, gas and water from the well and the volume of fluids injected into the well are allocated on a pro rata basis to the pools or zones using the flow allocation procedure approved under subsection 14 (2). Proration tests (2) The operator must ensure that sufficient proration tests are conducted to measure the rates at which fluids are produced from the well to ensure that the allocation of oil, gas and water production to the pools and zones as a result of the flow allocation procedure is accurate.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 77
Testing and maintenance 77 (1) An operator must ensure that (a) meters and other associated components of the flow system are calibrated and maintained to ensure their accuracy; (b) the equipment used to calibrate the flow system is calibrated in accordance with good measurement practices; and (c) any component of the flow system that may have an impact on the accuracy or integrity of the flow system and that is not functioning in accordance with the manufacturer’s specifications is repaired or replaced without delay or, if it is not possible to do so without delay, corrective measures are taken to minimize the impact on the accuracy and integrity of the flow system while the repair or replacement is in progress. Notice (2) The operator must ensure that a conservation officer is notified, as soon as the circumstances permit, of any modification to or malfunction or failure of any flow system component that may have an impact on the accuracy of the flow system and of the corrective measures taken.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 78
Calibration 78 An operator must ensure that (a) a conservation officer is notified of the calibration of any transfer meter prover or master meter used in conjunction with a transfer meter at least 30 days before the day on which it is calibrated or as agreed to in writing by the Chief Conservation Officer; and (b) following completion of the calibration, a copy of the calibration certificate is submitted to the Chief Conservation Officer as soon as the circumstances permit.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 79
Resource management 79 An operator must, in respect of the recovery of petroleum, ensure that (a) recovery from a pool or zone is maximized in accordance with good oilfield practices; (b) wells are located and operated to provide for maximum recovery from a pool or zone; and (c) if there is reason to believe that infill drilling or the implementation of an enhanced recovery plan might result in increased recovery from a pool or field, studies on those methods are conducted and submitted to the Board.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 80
Commingled production 80 (1) It is prohibited for an operator to engage in commingled production unless approved by the Board. Approval by the Board (2) The Board must approve commingled production if the operator demonstrates that it will maximize the recovery of petroleum. Measurement and allocation (3) If the operator engages in commingled production, it must ensure that the total volume and the rate of production of each fluid produced is measured and the volume from each pool or zone is allocated in accordance with the requirements set out in sections 74 to 78 .
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 81
Pilot scheme 81 (1) An operator may develop and implement a pilot scheme that applies technology in relation to the commercial production of petroleum from a pool, field or zone that is accessible from a production installation and in relation to which there is an approved development plan for the purpose of obtaining information on reservoir, production or technology performance in order to optimize production performance under the development plan or to determine whether the development plan requires an amendment for production performance to be optimized. Duration and interim evaluations (2) The Board must establish (a) the duration of the pilot scheme, based on the time required to achieve the stated objectives; and (b) the intervals at which interim evaluations of the pilot scheme are to be conducted and reported to the Board. Completion of pilot scheme (3) On completion of the pilot scheme, the operator must ensure that any production activities undertaken for the purpose of the scheme are discontinued.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 82
Prohibition against flaring or venting 82 It is prohibited for an operator to flare or vent gas unless (a) the Board authorizes flaring or venting as part of the authorization; (b) the flaring or venting occurs during a formation flow test approved by the Board under subsection 63 (5); or (c) it is necessary in order to remediate an emergency situation that may cause serious risk to human health or safety and the Board is notified, as soon as the circumstances permit, of the flaring or venting and of the volume flared or vented.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 83
Venting limit 83 (1) An operator must ensure that the volume of gas vented under paragraph 82 (a) per installation during a year is not greater than 15 000 standard m 3 . Definition of vented (2) For the purpose of subsection (1), vented means emitted in a controlled manner, other than as a result of combustion, from an installation due to (a) the design of equipment or operational procedures at the installation; or (b) the occurrence of an event that pressurizes the gas beyond the capacity of the equipment at the installation to retain the gas.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 84
Gas emissions 84 (1) The operator must ensure that the emissions of gas from the seals of a centrifugal compressor or reciprocating compressor at an installation are (a) captured and routed to gas conservation equipment or gas destruction equipment; or (b) routed to vents that release those emissions into the atmosphere. Flow rate measurement device (2) The operator must ensure that the flow rate of emissions of gas released from vents referred to in paragraph (1)(b) is measured by means of a continuous monitoring device that is (a) calibrated in accordance with the manufacturer’s recommendations such that its measurements have a maximum margin of error of ±10%; (b) operated continuously, other than during periods when it is undergoing normal servicing or timely repairs; and (c) equipped with an alarm that is triggered when the applicable flow rate limit referred to in subsections (3) and (4) for the vents of the compressor is reached. Flow rate limit — centrifugal compressor (3) The operator must ensure that the flow rate limit of emissions from the vents of a centrifugal compressor on an installation is (a) in the case of a compressor that is installed before January 1, 2023, (i) 0.68 standard m 3 /min if the compressor has a rated brake power of greater than or equal to 5 MW, and (ii) 0.34 standard m 3 /min if the compressor has a rated brake power of less than 5 MW; and (b) in the case of a compressor that is installed on or after January 1, 2023, 0.14 standard m 3 /min. Flow rate limit — reciprocating compressor (4) The operator must ensure that the flow rate limit of emissions that are from the rod packings and distance pieces of a reciprocating compressor on an installation is (a) if the compressor is installed before January 1, 2023, the product of 0.023 standard m 3 /min and the number of pressurized cylinders that the compressor has; or (b) if the compressor is installed on or after January 1, 2023, the product of 0.001 standard m 3 /min and the number of pressurized cylinders that the compressor has. Corrective measures (5) If the alarm referred to in paragraph (2)(c) is triggered, the operator must ensure that corrective measures are taken as soon as the circumstances permit to reduce the flow rate to below or equal to the applicable flow rate limit.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 85
Prohibition against oil burning 85 It is prohibited for an operator to burn oil unless (a) the Board authorizes burning as part of the authorization; (b) the burning occurs during a formation flow test approved by the Board under subsection 63 (5); or (c) it is necessary in order to remediate an emergency situation that may cause serious risk to human health or safety and the Board is notified, as soon as the circumstances permit, of the burning and of the amount burned.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 86
Determination of net environmental benefit 86 In determining for the purpose of subsection 166.1(3) of the Act whether the use of a spill-treating agent is likely to achieve a net environmental benefit, the Chief Conservation Officer must take into account (a) the assessment of the spill-treating agent’s efficacy referred to in paragraph 11 (4)(a); (b) the results of the analysis referred to in paragraph 11 (4)(b); (c) the circumstances referred to in paragraph 11 (4)(c); (d) the methods and protocols referred to in paragraph 11 (4)(d); (e) the monitoring plan referred to in paragraph 11 (4)(f); and (f) the results of any small-scale test conducted in respect of the agent.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 87
Small-scale test 87 (1) An operator must, in respect of any small-scale test of a spill-treating agent referred to in section 166.1 of the Act, ensure that (a) before the test is conducted, the Chief Conservation Officer approves the carrying out of the test; (b) during the test, the quantity of spill-treating agent applied is measured and recorded, the efficacy of the spill-treating agent is monitored and the factors that affect that efficacy are evaluated; and (c) after the test, the following information is submitted in writing, without delay, to the Chief Conservation Officer: (i) the volume of oil released and the volume treated, (ii) the quantity of spill-treating agent that was used to conduct the test, (iii) the circumstances under which the test was conducted, and (iv) the efficacy of the use of the spill-treating agent. Conditions (2) The following conditions must be met before a small-scale test is approved: (a) the operator must demonstrate that the quantity of spill-treating agent to be used in the test is the minimum required to evaluate the efficacy of its use; and (b) in the case of a request to conduct an offshore subsurface test, the operator must demonstrate that, due to physical and environmental conditions, a surface test cannot be done or its efficacy cannot be readily determined. Net environmental benefit already determined (3) No small-scale test is to be approved if the Chief Conservation Officer has made a determination for the purpose of section 166.1 of the Act regarding the net environmental benefit of the use of the spill-treating agent whose efficacy the test is intended to evaluate. Oral or written approval (4) Approval of a small-scale test may be provided orally or in writing but, if approval is provided orally, the Chief Conservation Officer must, as soon as the circumstances permit, provide to the operator written confirmation of the approval.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 88
Variation of approval 88 (1) The Chief Conservation Officer must vary the approval to use a spill-treating agent if new information indicates that a modification to the requirements set out in the approval is necessary to ensure that the approved use is likely to achieve a net environmental benefit. Revocation of approval (2) The Chief Conservation Officer must revoke the approval if new information indicates that, despite any modification, use of the agent will not likely achieve a net environmental benefit.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 89
Use of spill-treating agent 89 (1) An operator must ensure that any spill-treating agent is used in accordance with industry standards and best practices for spill-treating agent use, taking into account the local environment. Equipment and materials (2) The operator must ensure that all equipment and materials that are listed in the contingency plan as required by paragraph 11 (4)(e) are available and maintained in accordance with the manufacturers’ specifications and ready for use at all times. Monitoring plan implementation (3) The operator must implement the monitoring plan that is included in the contingency plan as required by paragraph 11 (4)(f) at the commencement of the use of a spill-treating agent in the case of a spill. Information to Chief Conservation Officer (4) The operator must inform the Chief Conservation Officer of the spill-treating agent’s efficacy, the effects of its use on the environment and any changes that may require a modification to its use.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 90
Conditions for suspension or abandonment 90 (1) An operator that suspends or abandons a well must ensure that the well (a) can be readily located; and (b) is left in a condition such that (i) all petroleum-bearing pools and zones and discrete pressure zones are isolated, and (ii) any formation fluid is prevented from flowing through or escaping from the well-bore. Verification of isolation (2) Before suspending or abandoning the well, the operator must verify the effectiveness of the isolations referred to in subparagraph (1)(b)(i) in accordance with the methods set out in its well approval application under paragraph 17 (4)(e).
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 91
Additional condition for suspension 91 An operator that suspends a well must ensure that it is inspected and monitored to maintain its integrity and prevent pollution.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 92
Additional condition for abandonment 92 The operator of a well must ensure that, on the abandonment of the well, the seabed is cleared of any material or equipment that might have an adverse effect on the marine environment or interfere with fishing activities or other uses of the sea.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 93
Conditions for drilling installation removal 93 It is prohibited for the operator of a drilling installation to remove the drilling installation from a well or cause it to be removed unless (a) the well has been abandoned, suspended or completed in accordance with these Regulations; or (b) the removal of the drilling installation is for emergency purposes.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 94
Vessel used in diving project 94 An operator that conducts a diving project must, in respect of a vessel used in the diving project, ensure that (a) the vessel is capable of providing the necessary dive support functions and operating safely; (b) the vessel is designed to withstand or avoid, without loss of its overall structural integrity or failure of its main safety functions, all foreseeable site-specific physical and environmental conditions or any foreseeable combination of those conditions; (c) the vessel is a Safety Convention vessel , as defined in section 2 of the Canada Shipping Act, 2001 , and holds a valid certificate of class issued by a classification society; (d) if a permanent diving system is installed on the vessel, the certificate of class referred to in paragraph (c) includes a valid class notation for diving issued by the classification society referred to in that paragraph; and (e) a competent third party has assessed and certified the sea fastening of any equipment that is temporarily installed on the vessel for the diving project.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 95
Dynamic positioning system 95 (1) An operator must ensure that the dynamic positioning system on a vessel that is used in a diving project (a) includes safety-critical systems and components with sufficient segregation and redundancy to maintain the vessel’s position in the event that credible scenarios of equipment failure, fire or flooding are realized; (b) includes systems to monitor the parameters of critical system operability and the integrity of the dynamic positioning system and to provide alerts for critical system faults; (c) has sufficient redundancy to protect divers while diving; (d) is designed based on numerical analysis and model testing to ensure that the vessel’s position reference and directional control can be maintained within specified tolerances that satisfy design operational requirements in relation to all functional loads and environmental loads to which the system may be subjected; and (e) is designed to ensure that, if the diving project involves saturation diving, the dynamic positioning system can withstand the loss from fire or flooding of all of its components situated in any one watertight compartment or fire subdivision of the vessel. Verification (2) After the design of the dynamic positioning system is completed, the operator must ensure that a failure modes and effects analysis is conducted to verify that the dynamic positioning system meets the requirements set out in subsection (1). Maintenance (3) The operator must ensure that the dynamic positioning system is maintained so that it continues to perform in accordance with its design specifications.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 96
Light dive craft 96 (1) The operator must ensure that any light dive craft that is used for a diving project is (a) fit for the purposes for which it is to be used; and (b) designed to withstand or avoid, without loss of its overall structural integrity or failure of its main safety functions, all foreseeable site-specific physical and environmental conditions or any foreseeable combination of those conditions. Dive support vessel (2) The operator must ensure, during all dives from a light dive craft, the availability of a dive support vessel that (a) is fitted with emergency equipment, including a fast rescue boat, that can provide assistance to the light dive craft in any foreseeable emergency situation; and (b) has a launch and recovery system for the light dive craft that has been verified and certified by the certifying authority as being fit for the purposes for which it is to be used. Definition of light dive craft (3) In this section, light dive craft means a small vessel or secondary craft that is equipped to deploy divers from a primary vessel.
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — 97
Definitions 97 The following definitions apply in this Part. air gap means the clearance between the highest water or ice surface that occurs during extreme environmental conditions and the lowest exposed part of an installation not designed to withstand wave or ice impingement. ( tirant d’air ) control station means a work area that is not continuously staffed that provides an alternative location to a control centre and the minimum necessary control equipment to enable essential management of the installation or of specific key systems. ( poste de contrôle ) damaged condition means, with respect to a floating platform, the condition of the platform after it has suffered damage up to the extent determined in accordance with the applicable provisions of the MODU Code or, in the case of a platform that is not a mobile offshore drilling unit, the applicable rules of a classification society. ( état d’avarie ) design service life means the anticipated period during which any installation, including its systems or equipment, is to be used for its intended purpose, with anticipated maintenance but without substantial repair. ( vie utile ) hazardous area means an area on an installation where flammable, explosive or combustible mixtures are or are likely to be present in sufficient quantities and for sufficient periods of time to require special precautions to be taken in the selection, installation or use of machinery and electrical equipment to prevent a fire or explosion. ( aire dangereuse ) IS Code means the annex to International Maritime Organization Resolution MSC.267(85), International Code on Intact Stability, 2008 . ( recueil IS ) MODU Code means the annex to International Maritime Organization Resolution A.1023(26), Code for the Construction and Equipment of Mobile Offshore Drilling Units, 2009 . ( Code MODU ) process vessel means a heater, dehydrator, separator, treater or any other pressurized vessel used in the processing or treatment of produced petroleum. ( cuve de traitement ) unattended installation means an installation on which persons are not normally present and in respect of which, when persons are present, it is for the purpose of performing operational duties, maintenance or inspections that will not require an overnight stay. ( installation non fréquentée )
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations
air gap means the clearance between the highest water or ice surface that occurs during extreme environmental conditions and the lowest exposed part of an installation not designed to withstand wave or ice impingement. ( tirant d’air )
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations
control station means a work area that is not continuously staffed that provides an alternative location to a control centre and the minimum necessary control equipment to enable essential management of the installation or of specific key systems. ( poste de contrôle )
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations
damaged condition means, with respect to a floating platform, the condition of the platform after it has suffered damage up to the extent determined in accordance with the applicable provisions of the MODU Code or, in the case of a platform that is not a mobile offshore drilling unit, the applicable rules of a classification society. ( état d’avarie )
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations
design service life means the anticipated period during which any installation, including its systems or equipment, is to be used for its intended purpose, with anticipated maintenance but without substantial repair. ( vie utile )
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations
hazardous area means an area on an installation where flammable, explosive or combustible mixtures are or are likely to be present in sufficient quantities and for sufficient periods of time to require special precautions to be taken in the selection, installation or use of machinery and electrical equipment to prevent a fire or explosion. ( aire dangereuse )
Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations — Canada–Nova Scotia Offshore Area Petroleum Operations Framework Regulations
IS Code means the annex to International Maritime Organization Resolution MSC.267(85), International Code on Intact Stability, 2008 . ( recueil IS )