GreatNorthCollective/greatnorth-canada-federal-laws-text huggingface dataset:
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 68
Well control 68 (1) An operator must ensure that adequate procedures, materials and equipment are in place and used throughout the life cycle of the well to prevent the loss of well control. Reliable well control equipment (2) The equipment referred to in subsection (1) must include reliable well control equipment to detect and control kicks, prevent blowouts and safely conduct all well operations. Shallow hazards (3) During well operations conducted without a riser, the operator must ensure that measures are implemented to reduce the risk of shallow hazards while drilling. Surface casing (4) The operator must ensure that the surface casing of the well is installed to a sufficient depth, and in a competent formation, to establish well control for the continuation of the drilling operations. Blowout preventer and barrier envelopes (5) After the surface casing has been installed and cemented, the operator must ensure that (a) a blowout preventer is installed before the casing shoe is drilled out; and (b) there are at least two independent barrier envelopes — each of which is to be verified by the operator — in place throughout the life cycle of the well. Barrier envelope failure (6) If there is a failure in a barrier envelope, the operator must ensure that no well operation, other than one that is intended to replace or restore the barrier envelope, takes place until the barrier envelope is replaced or restored. Replacement or restoration of barrier envelope (7) The operator must ensure that (a) the barrier envelope is replaced or restored as soon as the circumstances permit; (b) every effort is made for the replacement or restoration to conform to the original design specifications; and (c) the barrier envelope is verified after its replacement or restoration. Drilling fluid column (8) The operator must ensure that, during well operations, one of the two barrier envelopes is the drilling fluid column, except when drilling under-balanced or if, when a completion or test string is run, the other barrier envelope has already been installed downhole and tested. Pressure control equipment (9) The operator must ensure that all pressure control equipment associated with well operations is pressure-tested on installation and as often as necessary to ensure its continued safe operation. Corrective measures (10) If well control is lost or if safety, the protection of the environment or resource conservation is at risk, the operator must ensure that any necessary corrective measures are taken without delay.
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 69
Casing and wellhead system 69 (1) An operator must ensure that a casing and wellhead system is designed, taking into account the wellhead’s fatigue life, so that, throughout the life cycle of the well, (a) the well can be drilled safely, targeted formations can be evaluated and developed and waste can be prevented; (b) the maximum conditions, forces and stresses to which the casing and wellhead system may be subjected are withstood; and (c) the integrity of gas hydrate and permafrost zones is protected. Barrier analysis (2) The operator must ensure that, during the design of the casing and wellhead system, if the annulus is to be used for fluid production or injection, a barrier analysis is conducted to confirm that two barrier envelopes can be maintained in place throughout the life cycle of the well. Casing depth (3) The operator must ensure that each casing is installed at a depth that provides for adequate kick tolerance and safe well control. Wellhead fatigue life (4) The operator must ensure that well operations do not continue beyond the wellhead’s fatigue life. Cement slurry (5) The operator must ensure that the cement slurry is designed and installed so that, throughout the life cycle of the well, (a) the movement of formation fluids is prevented and, when required for safety, resource evaluation or waste prevention, the isolation of the petroleum and water zones is ensured; (b) support for the casing is provided; (c) corrosion of the casing over the cemented interval is minimized; and (d) the integrity of gas hydrate and permafrost zones is protected. Cement integrity and placement (6) The operator must ensure that the cement integrity and placement are verified, subject to subsection (7), through pressure-testing and, if the cement is a common barrier element of the two barrier envelopes or if confirmation of zonal isolation is required, also through logging. Other methods of verification (7) The cement integrity and placement may be verified using other methods if the operator demonstrates that those methods provide a level of verification that is equivalent to those referred to in subsection (6). Cement design and slurry analysis (8) The operator must ensure that the cement design is subjected to comprehensive laboratory testing and pre-cementing quality control, under all foreseeable conditions that could have an impact on cementing, so that the cement provides the expected isolation and can be efficiently installed. Waiting on cement time (9) The operator must ensure that, after cementing any casing or casing liner and before drilling out the casing shoe, the cement reaches the minimum compressive strength sufficient to support the casing and provide zonal isolation. Casing pressure testing (10) The operator must ensure that, after any casing is installed and cemented and before the casing shoe is drilled out, the casing is pressure-tested to the value required to confirm its integrity for maximum anticipated operating pressure throughout the life cycle of the well.
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 70
Formation leak-off or integrity test 70 (1) An operator must ensure that a formation leak-off test or a formation integrity test is conducted (a) before drilling more than 10 m of new formation below the shoe of any casing other than the conductor casing; and (b) before drilling more than 10 m when sidetracking from the previous casing string. Pressure (2) The formation leak-off test or formation integrity test must be conducted at a pressure that allows for safe drilling to the next casing depth and for the adequacy of the cement at the level of the shoe to be verified before drilling ahead.
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 71
Completion, testing and operation of development wells 71 (1) The operator of a development well must ensure that (a) the well is completed, tested and operated in a safe manner that allows for maximum recovery of petroleum without waste or pollution throughout the life cycle of the well; (b) except in the case of commingled production, each completion interval is isolated from any other porous or permeable interval penetrated by the well; (c) if applicable, the production of sand, carbonate or other solids is controlled and does not create a safety hazard or cause waste; (d) the setting depth of each packer is as deep as possible and is such that any leak through the production casing below the packer will be contained by the barrier envelope outside the casing; (e) the formation and any annulus seal can withstand the pressures and temperatures expected throughout the life cycle of the well; (f) if practicable, any mechanical well condition that may have an adverse effect on the production of petroleum from, or the injection of fluids into, the well is corrected; (g) the injection or production profile of the well is improved or the completion interval of the well is changed if it is necessary to do so to prevent waste; (h) if different pressure and inflow characteristics of two or more pools might adversely affect the recovery of petroleum from any of those pools, the well is operated as a single pool well or as a segregated multi-pool well; (i) during completion operations and before the removal of pressure control equipment and handover for operations, all barrier elements are tested to the maximum pressure to which they are anticipated to be subjected and, if possible, pressure testing is in the direction of flow; and (j) following any workover or intervention, any affected barrier elements are pressure-tested. Segregated multi-pool well (2) If the development well is a segregated multi-pool well, the operator must also ensure that (a) after the well is completed, segregation within and outside the well casing is verified; and (b) if there is reason to doubt that segregation is being maintained, a segregation test is conducted as soon as the circumstances permit. Definition of multi-pool well (3) In this section, multi-pool well means a well that is completed in more than one pool.
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 72
Production tubing 72 An operator must ensure that the production tubing used in a well is designed and maintained to be compatible with the fluids to which it will be exposed, to withstand the maximum conditions, forces and stresses to which it may be subjected and to maximize recovery of petroleum from the pool.
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 73
Safe operations and production 73 An operator must ensure that equipment and procedures are in place to recognize and control normal and abnormal operating conditions, for the purposes of allowing for safe and controlled well operations and production and of preventing pollution.
Canada–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 74
Flow and volume 74 (1) Subject to subsection (2), an operator must ensure that the following are measured: (a) the rate of flow and the volume of the fluid that is produced from each well; (b) the rate of flow and the volume of the fluid or waste material that is injected into each well; and (c) the volume of the fluid that is produced from each well that is used, flared, vented, burned or otherwise disposed of. Alternate measurements (2) Alternate measurements may be conducted if approved by the Board under section 14 . Method (3) The operator must ensure that all measurements are conducted using the flow system, flow calculation procedure and flow allocation procedure approved under subsection 14 (2).
Canada–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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–Newfoundland and Labrador Offshore Area Petroleum Operations Framework Regulations — 86
Determination of net environmental benefit 86 In determining for the purpose of subsection 161.1(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–Newfoundland and Labrador 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 161.1 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 161.1 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–Newfoundland and Labrador 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–Newfoundland and Labrador 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.