Energy

1.1 General

This Standard covers seamless pipe, electric-welded pipe (flash-welded pipe continuously welded and low-frequency electric-welded pipe excluded), and submerged-arc-welded pipe primarily intended for use in oil or gas pipeline systems.

Notes:

1) Flash-welded pipe is pipe manufactured by a process using electric-resistance heating to produce a simultaneous coalescence over the entire area of the abutting edges and the application of pressure for joining.

2) Low frequency is less than 70 kHz.

1.2 Outside diameter, grade, and category

Note: It is not intended that pipe be available in all combinations of size, grade, category, and manufacturing process. The individual pipe manufacturers should be consulted to ascertain the availability of specific pipe items.

1.2.1 Outside diameter

This Standard covers pipe having specified outside diameters (ODs) from 21.3 to 2032 mm. The standard ODs are given in Table B.1.

1.2.2 Grade

For other than sour service, this Standard covers pipe from Grade 241 to Grade 825. For sour service, this Standard covers pipe from Grade 241 to Grade 483.

Note: The standard grades are Grades 241, 290, 359, 386, 414, 448, 483, 550, 620, 690, and 825; however, intermediate grades may also be used.

1.2.3 Category

This Standard covers pipe in the following categories:

a) Category I: pipe without requirements for proven pipe body notch-toughness properties;

b) Category II: pipe with requirements for proven pipe body notch-toughness properties in the form of energy absorption and shear fracture areaappearance; and

c) Category III: pipe with requirements for proven pipe body notch-toughness properties in the form of energy absorption.

Note: Pipe cannot be classified as Category II or Category III if it has not been notch-toughness tested.

1.3 Terminology

In this Standard, “shall” is used to express a requirement, i.e., a provision that the user is obliged to satisfy in order to comply with the Standard; “should” is used to express a recommendation or that which is advised but not required; and “may” is used to express an option or that which is permissible within the limits of the Standard.

Notes accompanying clauses do not include requirements or alternative requirements; the purpose of a note accompanying a clause is to separate from the text explanatory or informative material.

Notes to tables and figures are considered part of the table or figure and may be written as requirements.

Annexes are designated normative (mandatory) or informative (non-mandatory) to define their application.

1.1 General

This Standard covers the manufacturing of factory-made cold bends, primarily intended for use in oil or gas pipeline systems.

1.2 Size, grade, and category

1.2.1 Size

This Standard covers cold bends having specified outside diameters (ODs) from 21.3 to 1219 mm (NPS 1/2 to NPS 48). The standard ODs are provided in CSA Z245.1 Table B.1.

1.2.2 Grade

For other than sour service, this Standard covers bends from Grade 241 to Grade 690. For sour service, this Standard covers bends from Grade 241 to Grade 483.

Note: The standard grades are 241, 290, 359, 386, 414, 448, 483, 550, 620, and 690 (see Table 3); however, intermediate grades can be used in accordance with Clause 8.2.2.

1.2.3 Category

This Standard covers cold bends in the following categories:

a) Category I: Cold bends without requirements for proven notch toughness properties; and

b) Category II: Cold bends with requirements for proven notch toughness properties for the cold bend body and cold bend weld.

Note: A cold bend cannot be classified as Category II if it has not been notch-toughness tested.

1.3 Terminology

In this Standard, “shall” is used to express a requirement, i.e., a provision that the user is obliged to satisfy in order to comply with the Standard; “should” is used to express a recommendation or that which is advised but not required; and “may” is used to express an option or that which is permissible within the limits of the Standard.

Notes accompanying clauses do not include requirements or alternative requirements; the purpose of a note accompanying a clause is to separate from the text explanatory or informative material.

Notes to tables and figures are considered part of the table or figure and may be written as requirements.

Annexes are designated normative (mandatory) or informative (non-mandatory) to define their application.

1.1 General

This Standard covers the manufacturing of factory-made induction bends, primarily intended for use in oil or gas pipeline systems.

1.2 Size, grade, and category

1.2.1 Size

This Standard covers induction bends having specified outside diameters (ODs) from 60.3 to 1524 mm (NPS 2 to NPS 60). The standard ODs are provided in CSA Z245.1 Table B.1.

1.2.2 Grade

For other than sour service, this Standard covers bends from Grade 241 to Grade 690. For sour service, this Standard covers bends from Grade 241 to Grade 483.

Note: The standard grades are 241, 290, 359, 386, 414, 448, 483, 550, 620, and 690 (see Table 3); however, intermediate grades can be used in accordance with Clause 8.2.2.

1.2.3 Category

This Standard covers induction bends in the following categories:

a) Category I: induction bends without requirements for proven notch toughness properties; and

b) Category II: induction bends with requirements for proven notch toughness properties for the induction bend body and induction bend weld.

Note: An induction bend cannot be classified as Category II if it has not been notch-toughness tested.

1.3 Terminology

In this Standard, “shall” is used to express a requirement, i.e., a provision that the user is obliged to satisfy in order to comply with the Standard; “should” is used to express a recommendation or that which is advised but not required; and “may” is used to express an option or that which is permissible within the limits of the Standard.

Notes accompanying clauses do not include requirements or alternative requirements; the purpose of a note accompanying a clause is to separate from the text explanatory or informative material.

Notes to tables and figures are considered part of the table or figure and may be written as requirements.

Annexes are designated normative (mandatory) or informative (non-mandatory) to define their application.

1.1 General

This Standard specifies criteria for establishing a security management program for petroleum and natural gas industry systems to ensure security threats and associated risks are identified and managed. This Standard provides mitigation and response processes and procedures to prevent and minimize the impact of security incidents that could adversely affect people, the environment, assets, and economic stability.

1.2 Applicability

This Standard applies to all petroleum and natural gas industry systems (as illustrated in Figures 2 and 3), including

a) pipeline systems handling

i) oil;

ii) gas;

iii) oil-field water;

iv) liquid products;

v) multi-phase fluids;

vi) slurries; and

vii) system supports, including

1) meter stations;

2) compressor stations;

3) pump stations;

4) tank farms;

5) terminals; and

6) all assets that support Items 1) to 5);

b) liquefied natural gas (LNG) production, storage, and handling facilities;

c) storage of hydrocarbons and hydrogen in underground formations;

d) petrochemical installations, including

i) refineries;

ii) gas processing plants;

iii) liquefied petroleum gas plants;

iv) synthetic natural gas plants; and

v) coal gasification plants;

e) oil and gas exploration, development, production, treatment, processing, and storage operations not covered in Items a) to d);

f) oil sands facilities; and

g) petroleum and natural gas wells.

Notes:

Examples of gas can include methane, carbon dioxide, and hydrogen.

Examples of liquid products can include methane, carbon dioxide, ammonia, and hydrogen.

The requirements of this Standard are applicable to all operators, regardless of the size or number of their assets.

1.3 Exclusions

Offshore petroleum and natural gas activity, petroleum and LNG tankers, and customers piping systems are outside the scope of this Standard. This Standard does not apply to offshore petroleum and natural gas activity, petroleum and liquefied natural gas (LNG) tankers, nor customers piping system. It also excludes security management for liquid or gaseous energy transported by rail, road, or ship.

Note: See Figures 2 and 3.

1.4 Terminology

In this Standard, “shall” is used to express a requirement, i.e., a provision that the user is obliged to satisfy in order to comply with the Standard; “should” is used to express a recommendation or that which is advised but not required; and “may” is used to express an option or that which is permissible within the limits of the Standard.

Notes accompanying clauses do not include requirements or alternative requirements; the purpose of a note accompanying a clause is to separate from the text explanatory or informative material.

Notes to tables and figures are considered part of the table or figure and may be written as requirements.

Annexes are designated normative (mandatory) or informative (non-mandatory) to define their application.

1.1 Minimum requirements

This Standard sets out minimum requirements for the design, construction, operation, maintenance, abandonment, and safety of hydrocarbon storage in underground reservoir formations and associated equipment. The equipment considered includes

a) storage wellhead and Christmas tree assemblies;

b) wells and subsurface equipment; and

c) safety equipment, including monitoring, control, and emergency shutdown systems.

Note: Hydrocarbons covered by this Standard are restricted to natural gas.

1.2 Scope diagram

The scope of this Standard is shown in Figure 1.

1.3 Exclusions

This Standard does not apply to

a) underground storage facilities for gases or fluids other than hydrocarbons, such as storage facilities used for air storage, unless these fluids are used specifically for the displacement of stored hydrocarbons;

b) underground storage facilities used for storing substances other than hydrocarbons, such as reaction chambers and waste disposal facilities;

c) underground storage in overburden materials involving the use of tanks, such as gasoline tanks;

d) design and fabrication of pressure vessels that are covered by pressure vessel codes;

e) heat exchangers, pumps, compressors, and piping in processing plant facilities, manufacturing plants, or industrial plants that are covered by appropriate codes;

f) gathering lines, flow lines, metering, compressors, and associated surface equipment beyond the first emergency shutdown valve (ESV) or block valve; and

g) storage of hydrocarbons containing hydrogen sulphide in concentrations greater than 10 mol/kmol.

1.4 Innovations

It is not the intent of this Standard to prevent the development of new equipment or practices, nor to prescribe how such innovations should be handled.

1.5 Precedence

Where the requirements of this Standard differ from the requirements of other standards or codes referenced herein, the requirements of this Standard take precedence.

1.6 Applicability

The requirements of this Standard do not apply retroactively to existing installations and installations under construction at the time of publication, but they do apply to the extension, replacement, maintenance, and upgrading of such installations.

1.7 Terminology

In this Standard, “shall” is used to express a requirement, i.e., a provision that the user is obliged to satisfy in order to comply with the standard; “should” is used to express a recommendation or that which is advised but not required; and “may” is used to express an option or that which is permissible within the limits of the Standard.

Notes accompanying clauses do not include requirements or alternative requirements; the purpose of a note accompanying a clause is to separate from the text explanatory or informative material.

Notes to tables and figures are considered part of the table or figure and may be written as requirements.

Annexes are designated normative (mandatory) or informative (non-mandatory) to define their application.

1.1 Facilities

1.1.1 Types of facilities

This Standard addresses the design and operation of EMPs for nuclear facilities as described in Clause 1.2 of CSA N288.0.

1.1.2 Facility lifecycle

The nature and extent of environmental monitoring requirements will change during the lifecycle of the facility. This Standard addresses monitoring performed during

a) site preparation, construction, and commissioning;

b) operations;

c) decommissioning; and

d) any period of institutional control that might follow closure of the facility.

Notes:

1) In Canada, baseline monitoring prior to the submission of an application for a licence to prepare a site might not be fully addressed by this Standard. For more information on pre-licensing baseline monitoring, see CNSC REGDOC-1.1.1, Section 3.4, Appendix B.3, and Appendix C, CNSC REGDOC-2.9.1, and BCMOE, 2016.

2) Data from baseline monitoring are generally used as an input into the ERA. Many of the recommendations and considerations provided within this Standard are applicable to environmental baseline activities. In addition, pre-licensing baseline data collection ideally places special emphasis on environmental factors and elements that might be carried forward to the EMP.

1.2 Operating conditions

1.2.1 Monitoring during normal operations

The monitoring described in this Standard is applicable where human and/or non-human biota might routinely be exposed to

a) low-level effluents and emissions of nuclear and hazardous substances released to the environment as the result of the normal operation of a nuclear facility; or

b) physical stressors imposed on the environment as the result of the normal operation of a nuclear facility.

1.2.2 Monitoring during accidental releases

This Standard does not address acute or high-level exposures that can result from accident scenarios (e.g., design basis accidents, beyond design basis accidents), although some parts of this Standard might be applicable to the monitoring of the long-term effect of such an event. In these cases, the operator of the facility is responsible for determining the applicability of the guidance.

1.2.3 Monitoring program boundary

This Standard addresses monitoring conducted in the environment within the spatial boundaries defined in the ERA. This monitoring starts beyond

a) the final point of control for an airborne or waterborne release; or

b) the facility boundary.

Note: The facility boundary may be the outer wall or foundation of the building housing the licensed activity. In Canada, the facility boundary may be the boundary of the protected area as defined in Section 9 of the Nuclear Security Regulations for nuclear facilities to which those Regulations apply.

Monitoring extends out to locations determined in the ERA by receptors and receptor range. The spatial boundaries might be different for each media.

Notes:

1) This Standard does not address effluent and emissions monitoring, which involves the monitoring of the release of nuclear and hazardous substances to the environment. See CSA N288.5 for additional information on effluent and emissions monitoring programs.

2) This Standard assumes that the exposure to nuclear or hazardous substances by persons working or visiting inside the facility boundary will be controlled through the facility radiation protection program, environmental protection program, or health and safety program.

1.3 Contaminants and physical stressors

This Standard provides guidance on monitoring for the contaminants and physical stressors in environmental media, as identified in the ERA and/or determined by the AHJ. These contaminants and physical stressors can include one or more of the following:

a) hazardous substances such as toxic, corrosive, or environmentally deleterious substances;

b) nuclear substances and radiation; and

c) physical stressors.

1.4 Receptors and biological effects

This Standard provides guidance on designing an EMP that can

a) provide the data necessary to assess potential biological effects on receptors; and

b) measure direct biological effects on receptors.

Notes:

1) Receptors are as identified in the ERA and/or as determined by the AHJ. The receptors can include human or non-human biota.

2) Measurements of effects in non-human biota (measurement endpoints) can occur at the level of an individual organism, a population, or a community. Often measurement endpoints at the individual level are intended to represent the potential for higher level effects (assessment endpoints) that are of primary concern to environment managers.

1.5 Interpretation of data

This Standard provides guidance on the interpretation of data collected by an EMP. However, users are cautioned that AHJs can impose requirements regarding data analysis and interpretation that differ from those described in this Standard. The operator of the nuclear facility is responsible for determining what data analysis and interpretation are necessary to ensure compliance with AHJ requirements.

1.6 Dose assessment

Although one of the objectives of an EMP may be to provide the data required to support radiation dose assessments or assessments of exposure to hazardous substances, this document does not address dose assessment methods for either human or non-human biota.

Note: Assessments of dose/exposure are normally part of the ERA and any subsequent assessments based on environmental monitoring data are ideally done the same way, using CSA N288.6 or equivalent standards and guidance that were used in the ERA or their most recent updates. Monitoring to support dose assessment is further addressed in Clause 7.4.

1.7 Reporting

Reporting requirements are outlined in Clause 8 of CSA N288.0. However, users are cautioned that AHJs may impose reporting requirements that differ from those described in this Standard and CSA N288.0. The operator of the nuclear facility is responsible for determining the required frequency and content of reports to AHJs necessary to ensure compliance.

1.8 Terminology

In this Standard, “shall” is used to express a requirement, i.e., a provision that the user is obliged to satisfy in order to comply with the standard; “should” is used to express a recommendation or that which is advised but not required; and “may” is used to express an option or that which is permissible within the limits of the Standard.

Notes accompanying clauses do not include requirements or alternative requirements; the purpose of a note accompanying a clause is to separate from the text explanatory or informative material.

Notes to tables and figures are considered part of the table or figure and may be written as requirements.

Annexes are designated normative (mandatory) or informative (non-mandatory) to define their application.

niveau plus élevé (limites d’évaluation), ce qui constitue la principale préoccupation des gestionnaires de l’environnement.

1.5     Interprétation des données

Cette norme énonce des lignes directrices visant l’interprétation des données recueillies dans le cadre d’un PSE. Cependant, les utilisateurs sont avisés que l’autorité compétente est susceptible d’imposer des exigences concernant l’analyse et l’interprétation des données qui diffèrent de celles prescrites dans cette norme. C’est à l’exploitant de l’installation nucléaire qu’il incombe de déterminer quelles analyses et interprétations des données sont nécessaires pour assurer la conformité aux exigences de l’autorité compétente.

1.6     Évaluation de la dose

Bien qu’un des objectifs d’un PSE peut être de fournir les données nécessaires à l’évaluation de la dose de rayonnement ou à l’évaluation de l’exposition à des substances dangereuses, le présent document ne traite pas des méthodes d’évaluation de la dose pour le biote humain ou non humain.

Note : L’évaluation de la dose/exposition fait normalement partie de l’ÉRE, et toute évaluation subséquente basée sur les données de surveillance environnementale est idéalement effectuée de la même manière, en se basant sur CSA N288.6 ou sur les mêmes normes et lignes directrices que celles utilisées dans l’ÉRE ou les éditions les plus récentes de ces documents. Voir l’article 7.4 pour obtenir d’autres renseignements sur la surveillance à l’appui de l’évaluation de la dose.

1.7     Établissement de rapport

Les exigences sur la consignation des résultats sont énoncées à l’article 8 de

CSA N288.0. Cependant, les utilisateurs sont avisés que l’autorité compétente peut imposer des exigences en matière d’établissement de rapport qui diffèrent de celles prescrites dans cette norme et dans CSA N288.0. C’est à l’exploitant de l’installation nucléaire qu’il incombe de déterminer la fréquence et la teneur des rapports présentés à l’autorité compétente pour assurer sa conformité.

1.8     Terminologie

Dans cette norme, le terme « doit » indique une exigence, c’est-à-dire une prescription que l’utilisateur doit respecter pour assurer la conformité à la norme; « devrait » indique une recommandation ou ce qu’il est conseillé mais non obligatoire de faire; et « peut » indique une possibilité ou ce qu’il est permis de faire.

Les notes qui accompagnent les articles ne comprennent pas de prescriptions ni de recommandations. Elles servent à séparer du texte les explications ou les renseignements qui ne font pas proprement partie de la norme.

Les notes au bas des figures et des tableaux font partie de ceux-ci et peuvent être rédigées comme des prescriptions.

Les annexes sont qualifiées de normatives (obligatoires) ou d’informatives (facultatives) pour en préciser l’application.