Draft Details

Designation:CSA Z260
Contact name:Sarah Elshafei
Review start date:Jul 2, 2024
Review end date:Aug 31, 2024
Contact email:thuy.ton(at)csagroup.org
Draft Scope/Description:

1.1 Service fluids

This Standard applies to oil and gas industry pipeline systems that convey

a) liquid hydrocarbons, including crude oil, multiphase fluids, condensate, liquid petroleum products;

b) natural gas liquids and liquefied petroleum gas;

c) oilfield water;

d) oilfield steam;

e) liquid or dense phase carbon dioxide; or

f) gas, including but not limited to natural gas, fuel gas, hydrogen and hydrogen blends, compressed air, carbon dioxide, and nitrogen.

See Figures 1 and 2.


1)     Non-hydrocarbon products used as process fluids and transported by operating companies by pipeline or within pipeline facilities, are considered within the scope of this Standard provided that those products are used in facilities connected to the pipeline system.

2)     Fluids used within equipment supporting the pipeline system operation, including consumables such as lubricating or hydraulic fluids, are considered within the scope of this Standard, provided that the equipment is connected to the pipeline system at the time of the PSSE.

1.2 Stations and equipment

This Standard applies to

a) piping and equipment in onshore liquids pipelines, tank farms, pump stations, pressure-regulating stations, and measuring stations;

b) oil pump stations, pipeline tank farms, and pipeline terminals;

c) pipe-type storage vessels;

d) carbon dioxide pipelines;

e) piping and equipment in onshore gas pipelines, compressor stations, measuring stations, and pressure-regulating stations;

f) gas storage lines and pipe-type and bottle-type gas storage vessels;

g) loading and unloading facilities for tankers or barge, truck, and rail when connected to the process; and

h) gas distribution systems.

See Figures 1 and 2.

Note: Refer to Annex D for more information.

1.3 Exclusions from standard application

This Standard does not apply to the following facilities and asset classes:

a)    gas piping beyond the outlet of the customer’s meter set assembly (e.g., piping covered by CSA B149.1);

b)   abandoned piping;

c)    in-plant piping for potable, make-up, boiler feed, or fire suppression water;

d)   vent piping for waste gases of any kind operating at or near atmospheric pressure;

e)    refueling facilities

f)    hydrocarbon storage in underground formations and associated equipment;

g)    piping in natural gas liquids extraction plants, gas processing plants, gas manufacturing plants, industrial plants, and mines;

h)   oil and gas production facilities;

i)     injection wells (i.e., CSA Z624 and CSA Z625); and

j)     LNG facilities, oil refineries, terminals other than pipeline terminals, and marketing bulk plants.


1) For items f) and h), users of this Standard should refer to IOGP Report 456 for metrics and guidance specifically focused on wells, production facilities, and storage in underground formations.

2) For items g) and jusers of this Standard should refer to ANSI/API RP 754 for metrics and guidance specifically focused on refineries, processing plants, and LNG facilities.

1.4 Exclusions from PSSEs in metrics

The following are not covered within this Standard as PSSEs or metrics:

a) planned and controlled venting or purging;

b) releases during transport of service fluids by means other than pipeline (e.g., road, rail, or ship) except when connected to the pipeline system for the purpose of loading and unloading;

c) emissions from permitted or regulated sources;

d) office, shop, and warehouse building events (e.g., office fires, spills, personnel illness, etc.);

e) personal safety events (e.g., slips, trips, falls) that are not directly associated with on-site response or exposure to a PSSE;

f) loss of primary containment from ancillary equipment not connected to the pipeline system (e.g., small sample containers);

g) activities associated with oil and gas pipeline system construction quality assurance, quality control, and research and development and laboratories;

h) releases during new oil and gas pipeline system construction that are positively isolated (e.g., blinded or air gapped) from a pipeline or process prior to commissioning and prior to the introduction of any service fluids. This includes trenchless methods such as horizontal directional drilling and boring (i.e., drilling mud releases);

i) releases during onsite fueling operations of mobile and stationary equipment (e.g., pick-up trucks, diesel generators, heavy equipment);

j) releases of hydraulic fluids from vehicles used onsite;

k) releases of water used for hydrostatically testing a pipeline (except where voluntarily included by the operating company as a leading indicator);

l) metrics used for greenhouse gas and carbon footprint emissions and accounting; or

m) metrics used for environmental management not related to spills and unintentional releases.

1.5 Interpretation of terms and annex designation

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.

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