75 - PETROLEUM AND RELATED TECHNOLOGIES
ICS 75 Details
PETROLEUM AND RELATED TECHNOLOGIES
ERDOL UND ZUGEHORIGE TECHNOLOGIEN
INDUSTRIE DU PETROLE ET TECHNOLOGIES ASSOCIEES
NAFTNA IN SORODNA TEHNOLOGIJA
General Information
Frequently Asked Questions
ICS 75 is a classification code in the International Classification for Standards (ICS) system. It covers "PETROLEUM AND RELATED TECHNOLOGIES". The ICS is a hierarchical classification system used to organize international, regional, and national standards, facilitating the search and identification of standards across different fields.
There are 11776 standards classified under ICS 75 (PETROLEUM AND RELATED TECHNOLOGIES). These standards are published by international and regional standardization bodies including ISO, IEC, CEN, CENELEC, and ETSI.
The International Classification for Standards (ICS) is a hierarchical classification system maintained by ISO to organize standards and related documents. It uses a three-level structure with field (2 digits), group (3 digits), and sub-group (2 digits) codes. The ICS helps users find standards by subject area and enables statistical analysis of standards development activities.
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This document specifies requirements and gives recommendations for the qualification and design, installation, testing and integrity management for the external application of composite repair systems to corroded or damaged piping and pipelines, tanks and vessels.
- Standard107 pagesEnglish languagesale 15% off
- Standard111 pagesFrench languagesale 15% off
This document specifies a test method for the determination of the content of n-butyl phenyl ether (BPE, CAS: 1126-79-0, also known as butoxy-benzene) in gas oils, kerosene, diesel fuel and biodiesel blends. The method uses a two-column gas chromatograph with an FID-type of detector. The application range is 0,27 mg/l to 19,75 mg/l of BPE, with the minimum and maximum reporting levels being 0,09 mg/l and 21,89 mg/l respectively.
NOTE This corresponds to 1 % to 185 % of the average marking level of the ACCUTRACE™ Plus required by Commission Implementing Decision (EU) 2022/197 [1] of 17 January 2022 establishing a common fiscal marker for gas oils and kerosene.
The method is found to be applicable to determinations beyond this range or for specific other chemical markers that fall within the distillation temperature range of middle-distillates, but for that no precision has been determined.
WARNING — The use of this document can involve hazardous materials, operations and equipment. This document does not purport to address all of the safety problems associated with its use. It is the responsibility of the user of this document to establish appropriate safety and health practices and to determine the applicability of regulatory limitations prior to use.
- Standard17 pagesEnglish languagee-Library read for1 day
This document specifies a test method for the determination of the content of n-butyl phenyl ether (BPE, CAS: 1126-79-0, also known as butoxy-benzene) in gas oils, kerosene, diesel fuel and biodiesel blends. The method uses a two-column gas chromatograph with an FID-type of detector. The application range is 0,27 mg/l to 19,75 mg/l of BPE, with the minimum and maximum reporting levels being 0,09 mg/l and 21,89 mg/l respectively.
NOTE This corresponds to 1 % to 185 % of the average marking level of the ACCUTRACE™ Plus required by Commission Implementing Decision (EU) 2022/197 [1] of 17 January 2022 establishing a common fiscal marker for gas oils and kerosene.
The method is found to be applicable to determinations beyond this range or for specific other chemical markers that fall within the distillation temperature range of middle-distillates, but for that no precision has been determined.
WARNING — The use of this document can involve hazardous materials, operations and equipment. This document does not purport to address all of the safety problems associated with its use. It is the responsibility of the user of this document to establish appropriate safety and health practices and to determine the applicability of regulatory limitations prior to use.
- Standard17 pagesEnglish languagee-Library read for1 day
This document gives requirements for the design, fabrication, installation, commissioning and integrity management of workover rigs on offshore fixed platforms. This document is not applicable to workover equipment: installed on mobile or floating offshore units; intended for onshore use; coiled tubing unit or snubbing unit.
- Standard65 pagesEnglish languagesale 15% off
- Standard65 pagesFrench languagesale 15% off
This document defines fundamental definitions for enhanced oil recovery (EOR) concepts and core methodologies, specifically addressing thermal recovery, gas flooding, chemical flooding, and microbial enhanced oil recovery technologies.
- Standard5 pagesEnglish languagesale 15% off
This document provides two broad types of requirements for the determination and use of meteorological and oceanographic (metocean) conditions for the design, construction and operation of offshore structures:
those related to the determination of environmental conditions in general, together with the metocean parameters that are required to adequately describe them;
those related to the characterization and use of metocean parameters for the design, the construction activities or the operation of offshore structures.
This document covers the following environmental conditions and metocean parameters:
extreme and abnormal values of metocean parameters that recur with given return periods that are considerably longer than the design service life of the structure;
long-term distributions of metocean parameters in the form of cumulative, conditional, marginal or joint statistics of metocean parameters;
normal environmental conditions that are expected to occur frequently during the design service life of the structure.
Metocean parameters specified in this document are applicable to:
the determination of actions for the design of new structures;
the determination of actions for the assessment of existing structures;
the site-specific assessment of mobile offshore units;
the determination of limiting environmental conditions, weather windows, actions and action effects for pre-service and post-service situations (i.e. fabrication, transportation and installation or decommissioning and removal of a structure);
the operation of the platform, where appropriate.
It is beyond the scope of this document to provide detailed instructions that can be followed to produce reliable estimates of extreme or abnormal conditions in all areas and in all cases.
- Standard340 pagesEnglish languagee-Library read for1 day
This document provides requirements for subsurface flow-control devices used in side-pocket mandrels intended for use in the worldwide petroleum and natural gas industry. This document addresses injection-pressure-operated (IPO), production-pressure-operated (PPO), pilot, orifice, tubing-retrievable, and dummy flow-control devices. It includes requirements for selecting, designing, manufacturing, quality control, testing, and preparation for the shipping of flow-control devices. Additionally, it includes information regarding performance testing and calibration requirements.
The installation and retrieval of flow-control devices is outside the scope of this document. Additionally, this document is not applicable to flow-control devices with concentric axes.
This document does not include requirements for side-pocket mandrels, running, pulling, kick-over tools, or latches. Reconditioning of used flow-control devices is outside the scope of this document.
This document supplements API Spec 19G2, 2nd edition (2020), the requirements of which are applicable with the exceptions specified in this document.
- Draft9 pagesEnglish languagee-Library read for1 day
This document specifies requirements and guidance for the installation on and removal from site of independent leg jack‑ups for use in the oil and gas industries including lower carbon energy. It addresses the assessment of: the installation operation from when the jack-up enters the defined safety zone of the host platform or the intended site to when it is elevated to the operating hull elevation above LAT and is ready for operations; the removal operation from when the jack-up is ready to jack-down to when it departs the defined safety zone. NOTE 1 Whilst this document is for independent leg jack-ups, many of the provisions can be applied to mat-supported jack-ups. When the jack-up has propulsion assist or is self-propelled, the provisions of this document related to positioning can be replaced or supplemented as appropriate. This document excludes the move of the jack-up between sites and elevated operations, which are covered respectively by IMO/Class and ISO 19905-1. NOTE 2 Whilst this document addresses the installation and removal of a jack-up at a site, RMPs normally include the move of the jack-up between sites (see example RMP in Annex E).
- Standard95 pagesEnglish languagesale 15% off
- Standard97 pagesFrench languagesale 15% off
This document specifies methodologies for:
the design, analysis and evaluation of stationkeeping systems for floating offshore structures;
the assessment of stationkeeping systems for site-specific applications of mobile offshore units and construction units.
Originally developed for floating structures used in the oil and gas industry, this document is now also used in the renewable energy sector. The extent of application of this document to floating structures used in other industries is at the discretion of the relevant standard entity and its users. For example, IEC 61400-3-2 for floating wind applies this document to determine stationkeeping system responses while incorporating its own load conditions, safety factors, and environmental return periods.
This document is applicable to the following types of stationkeeping systems, which are either covered directly in this document or through reference to other guidelines:
spread mooring systems;
single point mooring systems;
dynamic positioning systems;
thruster-assisted mooring systems.
This document is not applicable to:
stationkeeping systems which do not have redundancy against failure of any single component, e.g., single anchor leg moorings (SALMs);
stationkeeping systems which use any means other than mooring lines or thrusters such as tower soft yoke systems, or tension leg platforms (TLPs) that use tendons.
The requirements for this document address spread mooring systems and single point mooring systems with mooring lines composed of steel chain, steel wire or synthetic fibre rope.
This document is applicable to all aspects of the life cycle of mooring systems. It includes requirements relating to the selection of mooring components, mooring system configuration and performance, components design, installation, post-installation survey, and as-installed assessments as needed for mooring integrity management.
For mooring systems deployed in ice-prone environments, additional requirements in ISO 19906 apply.
- Standard202 pagesEnglish languagee-Library read for1 day
This document provides requirements for subsurface flow-control devices used in side-pocket mandrels intended for use in the worldwide petroleum and natural gas industry. This document addresses injection-pressure-operated (IPO), production-pressure-operated (PPO), pilot, orifice, tubing-retrievable, and dummy flow-control devices. It includes requirements for selecting, designing, manufacturing, quality control, testing, and preparation for the shipping of flow-control devices. Additionally, it includes information regarding performance testing and calibration requirements. The installation and retrieval of flow-control devices is outside the scope of this document. Additionally, this document is not applicable to flow-control devices with concentric axes. This document does not include requirements for side-pocket mandrels, running, pulling, kick-over tools, or latches. Reconditioning of used flow-control devices is outside the scope of this document. This document supplements API Spec 19G2, 2nd edition (2020), the requirements of which are applicable with the exceptions specified in this document.
- Standard4 pagesEnglish languagesale 15% off
- Standard5 pagesFrench languagesale 15% off
This document specifies requirements and test methods for pipes and fittings which are part of piping systems for the rehabilitation, by means of renovation and trenchless replacement, of underground gas supply networks.
It is applicable to polyethylene (PE) pipes, fittings and assemblies, as manufactured and as installed. It is not applicable to the existing pipeline.
This document is applicable to the following technique families for renovation, intended to be used at an operating temperature of 20 °C as a reference temperature:
lining with continuous pipes;
lining with close-fit pipes.
This document is applicable to the following technique families for trenchless replacement, intended to be used at an operating temperature of 20 °C as a reference temperature:
pipe bursting and pipe extraction;
horizontal directional drilling and impact moling.
This document is applicable to:
PE solid wall single layered pipes (nominal outside diameter, dn), including any identification stripes;
PE pipes with co-extruded layers on either or both the outside and inside of the pipe (total outside diameter, dn), as specified in Annex D, where all layers have the same minimum required strength (MRS) rating.
Furthermore, when used with lining with continuous pipes and trenchless replacement, this document is applicable to:
PE coated pipes (outside diameter, dn) having a peelable, contiguous, thermoplastics additional layer on the outside of the pipe (“coated pipe”), as specified in Annex D.
NOTE When used with lining with close-fit lining pipes, the lining pipe is reduced in the factory or on site to provide a close-fitting independent or interactive pressure pipe liner.
This document is applicable to jointing by means of butt fusion and electrofusion and to fabricated and injection-moulded fittings and mechanical connections of PE.
This document is not applicable to push-fit jointed discrete pipes assembled as part of the trenchless installation process.
- Standard50 pagesEnglish languagee-Library read for1 day
This document:
— provides the general part of the method to calculate the greenhouse gas (GHG) emissions throughout the liquefied natural gas (LNG) chain, a means to determine their carbon footprint;
— defines preferred units of measurement and necessary conversions;
— recommends instrumentation and estimation methods to monitor and report GHG emissions. Some emissions are measured; and some are estimated.
This document covers all facilities in the LNG chain. The facilities are considered “under operation”, including emissions associated with initial start-up, maintenance, turnaround and restarts after maintenance or upset. The construction, commissioning, extension and decommissioning phases are excluded from this document but can be assessed separately.
This document covers all GHG emissions. These emissions spread across scope 1, scope 2 and scope 3 of the responsible organization. Scope 1, 2 and 3 are defined in this document. All emissions sources are covered including flaring, combustion, cold vents, process vents, fugitive leaks and emissions associated with imported energy.
This document describes the allocation of GHG emissions to LNG and other hydrocarbon products where other products are produced (e.g. LPG, domestic gas, condensates, sulfur).
This document does not cover specific requirements on natural gas production and transport to LNG plant, liquefaction, shipping and regasification.
This document is applicable to the LNG industry.
- Standard31 pagesEnglish languagee-Library read for1 day
This document provides a method to calculate the greenhouse gas (GHG) emissions during natural gas production (onshore or offshore), gas processing and gas transport to liquefied natural gas (LNG) liquefaction plant.
NOTE It can be applied to other gases as biogas or non-traditional types of natural gas.
This document covers all facilities associated with producing natural gas, including:
— drilling (exploration, appraisal, and development) and production wells;
— gas gathering network and boosting stations (if any);
— gas processing facilities (if any), transport gas pipelines with compression stations (if any) up to inlet valve of LNG liquefaction plant.
This document covers facilities associated with producing other products (such as, but not limited to, domestic gas, condensate, Liquefied Petroleum Gas (LPG), sulphur, power export) to the extent required to allocate GHG emissions to each product.
This document covers the upstream facilities “under operation”, including emissions associated with commissioning, initial start-up and restarts after maintenance or upset. This document does not cover the exploration, construction and decommissioning phases or the losses from vegetation coverage.
This document covers all GHG emissions associated with production, process and transport of natural gas to the LNG liquefaction plant. These emissions spread across scope 1, scope 2 and scope 3 of the responsible organization, as defined in ISO 6338-1. All emissions sources are covered including flaring, combustion, cold vents, process vents, fugitive leaks and emissions associated with imported energy. Gases covered include CO2, CH4, N2O and fluorinated gases.
This document does not cover compensation.
This document defines preferred units of measurement and necessary conversions.
This document also recommends instrumentation and estimations methods to monitor and report GHG emissions. Some emissions are measured; and some are estimated.
- Standard17 pagesEnglish languagee-Library read for1 day
This document provides two broad types of requirements for the determination and use of meteorological and oceanographic (metocean) conditions for the design, construction and operation of offshore structures:
those related to the determination of environmental conditions in general, together with the metocean parameters that are required to adequately describe them;
those related to the characterization and use of metocean parameters for the design, the construction activities or the operation of offshore structures.
This document covers the following environmental conditions and metocean parameters:
extreme and abnormal values of metocean parameters that recur with given return periods that are considerably longer than the design service life of the structure;
long-term distributions of metocean parameters in the form of cumulative, conditional, marginal or joint statistics of metocean parameters;
normal environmental conditions that are expected to occur frequently during the design service life of the structure.
Metocean parameters specified in this document are applicable to:
the determination of actions for the design of new structures;
the determination of actions for the assessment of existing structures;
the site-specific assessment of mobile offshore units;
the determination of limiting environmental conditions, weather windows, actions and action effects for pre-service and post-service situations (i.e. fabrication, transportation and installation or decommissioning and removal of a structure);
the operation of the platform, where appropriate.
It is beyond the scope of this document to provide detailed instructions that can be followed to produce reliable estimates of extreme or abnormal conditions in all areas and in all cases.
- Standard340 pagesEnglish languagee-Library read for1 day
This document specifies an ultraviolet (UV) fluorescence test method for the determination of the sulfur content of the following products:
having sulfur contents in the range 3 mg/kg to 500 mg/kg:
motor gasolines containing up to a mass fraction of 3,7 % (3,7 % (m/m)) of oxygen [including those blended with a volume fraction of ethanol up to about 10 % (10 % (V/V))];
diesel fuels, including those containing up to a volume fraction of about 50 % of fatty acid methyl ester (FAME);
having sulfur contents in the range of 3 mg/kg to 45 mg/kg:
synthetic fuels, such as hydrotreated vegetable oil (HVO) and gas to liquid (GTL);
having sulfur contents in the range of 3 mg/kg to 30 mg/kg:
neat FAME (B100) and diesel fuels containing volume fraction of more than 50 % of FAME.
Other products (for example process feeds and effluents) can be analysed and other sulfur contents can be determined according to this test method, however, no precision data for products other than automotive fuels and for results outside the specified range have been established for this document. Halogens interfere with this detection technique at concentrations above approximately 3 500 mg/kg.
- Standard20 pagesEnglish languagee-Library read for1 day
This document contains requirements for seismic design and assessment of offshore structures.
This document includes recommendations for the effects of seismic events on floating structures.
This document addresses specifically the design and assessment of offshore structures subjected to earthquake-induced ground motions. It also covers briefly other geologically induced hazards such as liquefaction, slope instability, fault surface displacement, tsunamis, mud volcanoes and shock waves.
This document provides requirements for site-specific probabilistic seismic hazard analysis for offshore structures in high seismic areas and for offshore structures with high consequence levels.
- Standard106 pagesEnglish languagee-Library read for1 day
This document specifies requirements and gives recommendations for the pre-installation surveys, design, materials, equipment, installation, commissioning, operation, inspection, and maintenance of cathodic protection systems for the external surface of on-land pipelines.
This document is applicable to on-land pipelines and piping systems used in other industries and transporting other media such as industrial gases, waters, or slurries.
Throughout this document, on-land pipelines mean:
pipelines that are buried;
landfalls of offshore pipeline sections protected by onshore based cathodic protection installations;
immersed sections of on-land pipelines such as river or lake crossings.
This document is applicable to pipelines of carbon steel, stainless steel, cast iron, galvanized steel, and copper.
This document does not apply to pipelines made of reinforced concrete (see ISO 12696).
- Standard94 pagesEnglish languagee-Library read for1 day
This document provides two broad types of requirements for the determination and use of meteorological and oceanographic (metocean) conditions for the design, construction and operation of offshore structures: those related to the determination of environmental conditions in general, together with the metocean parameters that are required to adequately describe them; those related to the characterization and use of metocean parameters for the design, the construction activities or the operation of offshore structures. This document covers the following environmental conditions and metocean parameters: extreme and abnormal values of metocean parameters that recur with given return periods that are considerably longer than the design service life of the structure; long-term distributions of metocean parameters in the form of cumulative, conditional, marginal or joint statistics of metocean parameters; normal environmental conditions that are expected to occur frequently during the design service life of the structure. Metocean parameters specified in this document are applicable to: the determination of actions for the design of new structures; the determination of actions for the assessment of existing structures; the site-specific assessment of mobile offshore units; the determination of limiting environmental conditions, weather windows, actions and action effects for pre-service and post-service situations (i.e. fabrication, transportation and installation or decommissioning and removal of a structure); the operation of the platform, where appropriate. It is beyond the scope of this document to provide detailed instructions that can be followed to produce reliable estimates of extreme or abnormal conditions in all areas and in all cases.
- Standard332 pagesEnglish languagesale 15% off
- Standard353 pagesFrench languagesale 15% off
This document establishes the terms and definitions that are used in the field of natural gas, natural gas substitutes, mixtures of natural gas with gaseous fuels (such as unconventional and renewable gases) and wet gas.
- Standard18 pagesEnglish languagesale 15% off
- Draft25 pagesFrench languagesale 15% off
This document specifies a method for determining the phase equilibrium point of natural gas hydrates in a laboratory setting under constant volume conditions, including the principle, reagents and materials, apparatus, procedure, expression of results, test report and precision. This document applies to laboratory simulations of hydrate formation and decomposition processes. It involves the analysis of collected temperature and pressure data to determine the phase equilibrium temperature of hydrates.
- Standard20 pagesEnglish languagesale 15% off
This document specifies requirements and test methods for pipes and fittings which are part of piping systems for the rehabilitation, by means of renovation and trenchless replacement, of underground gas supply networks.
It is applicable to polyethylene (PE) pipes, fittings and assemblies, as manufactured and as installed. It is not applicable to the existing pipeline.
This document is applicable to the following technique families for renovation, intended to be used at an operating temperature of 20 °C as a reference temperature:
lining with continuous pipes;
lining with close-fit pipes.
This document is applicable to the following technique families for trenchless replacement, intended to be used at an operating temperature of 20 °C as a reference temperature:
pipe bursting and pipe extraction;
horizontal directional drilling and impact moling.
This document is applicable to:
PE solid wall single layered pipes (nominal outside diameter, dn), including any identification stripes;
PE pipes with co-extruded layers on either or both the outside and inside of the pipe (total outside diameter, dn), as specified in Annex D, where all layers have the same minimum required strength (MRS) rating.
Furthermore, when used with lining with continuous pipes and trenchless replacement, this document is applicable to:
PE coated pipes (outside diameter, dn) having a peelable, contiguous, thermoplastics additional layer on the outside of the pipe (“coated pipe”), as specified in Annex D.
NOTE When used with lining with close-fit lining pipes, the lining pipe is reduced in the factory or on site to provide a close-fitting independent or interactive pressure pipe liner.
This document is applicable to jointing by means of butt fusion and electrofusion and to fabricated and injection-moulded fittings and mechanical connections of PE.
This document is not applicable to push-fit jointed discrete pipes assembled as part of the trenchless installation process.
- Standard50 pagesEnglish languagee-Library read for1 day
This document specifies methodologies for:
the design, analysis and evaluation of stationkeeping systems for floating offshore structures;
the assessment of stationkeeping systems for site-specific applications of mobile offshore units and construction units.
Originally developed for floating structures used in the oil and gas industry, this document is now also used in the renewable energy sector. The extent of application of this document to floating structures used in other industries is at the discretion of the relevant standard entity and its users. For example, IEC 61400-3-2 for floating wind applies this document to determine stationkeeping system responses while incorporating its own load conditions, safety factors, and environmental return periods.
This document is applicable to the following types of stationkeeping systems, which are either covered directly in this document or through reference to other guidelines:
spread mooring systems;
single point mooring systems;
dynamic positioning systems;
thruster-assisted mooring systems.
This document is not applicable to:
stationkeeping systems which do not have redundancy against failure of any single component, e.g., single anchor leg moorings (SALMs);
stationkeeping systems which use any means other than mooring lines or thrusters such as tower soft yoke systems, or tension leg platforms (TLPs) that use tendons.
The requirements for this document address spread mooring systems and single point mooring systems with mooring lines composed of steel chain, steel wire or synthetic fibre rope.
This document is applicable to all aspects of the life cycle of mooring systems. It includes requirements relating to the selection of mooring components, mooring system configuration and performance, components design, installation, post-installation survey, and as-installed assessments as needed for mooring integrity management.
For mooring systems deployed in ice-prone environments, additional requirements in ISO 19906 apply.
- Standard202 pagesEnglish languagee-Library read for1 day
This document specifies an ultraviolet (UV) fluorescence test method for the determination of the sulfur content of the following products:
having sulfur contents in the range 3 mg/kg to 500 mg/kg:
motor gasolines containing up to a mass fraction of 3,7 % (3,7 % (m/m)) of oxygen [including those blended with a volume fraction of ethanol up to about 10 % (10 % (V/V))];
diesel fuels, including those containing up to a volume fraction of about 50 % of fatty acid methyl ester (FAME);
having sulfur contents in the range of 3 mg/kg to 45 mg/kg:
synthetic fuels, such as hydrotreated vegetable oil (HVO) and gas to liquid (GTL);
having sulfur contents in the range of 3 mg/kg to 30 mg/kg:
neat FAME (B100) and diesel fuels containing volume fraction of more than 50 % of FAME.
Other products (for example process feeds and effluents) can be analysed and other sulfur contents can be determined according to this test method, however, no precision data for products other than automotive fuels and for results outside the specified range have been established for this document. Halogens interfere with this detection technique at concentrations above approximately 3 500 mg/kg.
- Standard20 pagesEnglish languagee-Library read for1 day
This document provides a method to calculate the GHG emissions from an LNG liquefaction plant, onshore or offshore.
The frame of this document ranges from the inlet flange of the LNG plant’s inlet facilities up to and including the offloading arms to truck, ship or railcar loading. The upstream supply of gas up to the inlet flange of the inlet facilities and the distribution of LNG downstream of the loading arms are only covered in general terms.
This document covers:
— all facilities associated with producing LNG, including reception facilities, condensate unit (where applicable), pre-treatment units (including but not limited to acid gas removal, dehydration, mercury removal, heavies removal), LPG extraction and fractionation (where applicable), liquefaction, LNG storage and loading, Boil-Off-Gas handling, flare and disposal systems, imported electricity or on-site power generation and other plant utilities and infrastructure (e.g. marine and transportation facilities).
— natural gas liquefaction facilities associated with producing other products (e.g. domestic gas, condensate, LPG, sulphur, power export) to the extent required to allocate GHG emissions to the different products.
— all GHG emissions associated with producing LNG. These emissions spread across scope 1, scope 2 and scope 3 of the responsible organization. Scope 1, 2 and 3 are defined in this document. All emissions sources are covered including flaring, combustion, cold vents, process vents, fugitive leaks and emissions associated with imported energy.
The LNG plant is considered “under operation”, including emissions associated with initial start-up, maintenance, turnaround and restarts after maintenance or upset. The construction, commissioning, extension and decommissioning phases are excluded from this document but can be assessed separately.
The emissions resulting from boil-off gas management during loading of the ship or any export vehicle are covered by this document. The emissions from a ship at berth, e.g. mast venting are not covered by this document.
This document describes the allocation of GHG emissions to LNG and other hydrocarbon products where other products are produced (e.g. LPG, domestic gas, condensates, sulphur, etc.).
This document defines preferred units of measurement and necessary conversions.
This document also recommends instrumentation and estimations methods to monitor and report GHG emissions. Some emissions are measured and some are estimated.
This document is applicable to the LNG industry.
Applications include the provision of method to calculate GHG emissions through a standardized and auditable method, a means to determine their carbon footprint.
- Standard39 pagesEnglish languagee-Library read for1 day
This document:
— provides the general part of the method to calculate the greenhouse gas (GHG) emissions throughout the liquefied natural gas (LNG) chain, a means to determine their carbon footprint;
— defines preferred units of measurement and necessary conversions;
— recommends instrumentation and estimation methods to monitor and report GHG emissions. Some emissions are measured; and some are estimated.
This document covers all facilities in the LNG chain. The facilities are considered “under operation”, including emissions associated with initial start-up, maintenance, turnaround and restarts after maintenance or upset. The construction, commissioning, extension and decommissioning phases are excluded from this document but can be assessed separately.
This document covers all GHG emissions. These emissions spread across scope 1, scope 2 and scope 3 of the responsible organization. Scope 1, 2 and 3 are defined in this document. All emissions sources are covered including flaring, combustion, cold vents, process vents, fugitive leaks and emissions associated with imported energy.
This document describes the allocation of GHG emissions to LNG and other hydrocarbon products where other products are produced (e.g. LPG, domestic gas, condensates, sulfur).
This document does not cover specific requirements on natural gas production and transport to LNG plant, liquefaction, shipping and regasification.
This document is applicable to the LNG industry.
- Standard31 pagesEnglish languagee-Library read for1 day
This document provides a method to calculate the greenhouse gas (GHG) emissions during natural gas production (onshore or offshore), gas processing and gas transport to liquefied natural gas (LNG) liquefaction plant.
NOTE It can be applied to other gases as biogas or non-traditional types of natural gas.
This document covers all facilities associated with producing natural gas, including:
— drilling (exploration, appraisal, and development) and production wells;
— gas gathering network and boosting stations (if any);
— gas processing facilities (if any), transport gas pipelines with compression stations (if any) up to inlet valve of LNG liquefaction plant.
This document covers facilities associated with producing other products (such as, but not limited to, domestic gas, condensate, Liquefied Petroleum Gas (LPG), sulphur, power export) to the extent required to allocate GHG emissions to each product.
This document covers the upstream facilities “under operation”, including emissions associated with commissioning, initial start-up and restarts after maintenance or upset. This document does not cover the exploration, construction and decommissioning phases or the losses from vegetation coverage.
This document covers all GHG emissions associated with production, process and transport of natural gas to the LNG liquefaction plant. These emissions spread across scope 1, scope 2 and scope 3 of the responsible organization, as defined in ISO 6338-1. All emissions sources are covered including flaring, combustion, cold vents, process vents, fugitive leaks and emissions associated with imported energy. Gases covered include CO2, CH4, N2O and fluorinated gases.
This document does not cover compensation.
This document defines preferred units of measurement and necessary conversions.
This document also recommends instrumentation and estimations methods to monitor and report GHG emissions. Some emissions are measured; and some are estimated.
- Standard17 pagesEnglish languagee-Library read for1 day
This document contains requirements for seismic design and assessment of offshore structures.
This document includes recommendations for the effects of seismic events on floating structures.
This document addresses specifically the design and assessment of offshore structures subjected to earthquake-induced ground motions. It also covers briefly other geologically induced hazards such as liquefaction, slope instability, fault surface displacement, tsunamis, mud volcanoes and shock waves.
This document provides requirements for site-specific probabilistic seismic hazard analysis for offshore structures in high seismic areas and for offshore structures with high consequence levels.
- Standard106 pagesEnglish languagee-Library read for1 day
This document provides a method to calculate the GHG emissions from an LNG liquefaction plant, onshore or offshore.
The frame of this document ranges from the inlet flange of the LNG plant’s inlet facilities up to and including the offloading arms to truck, ship or railcar loading. The upstream supply of gas up to the inlet flange of the inlet facilities and the distribution of LNG downstream of the loading arms are only covered in general terms.
This document covers:
— all facilities associated with producing LNG, including reception facilities, condensate unit (where applicable), pre-treatment units (including but not limited to acid gas removal, dehydration, mercury removal, heavies removal), LPG extraction and fractionation (where applicable), liquefaction, LNG storage and loading, Boil-Off-Gas handling, flare and disposal systems, imported electricity or on-site power generation and other plant utilities and infrastructure (e.g. marine and transportation facilities).
— natural gas liquefaction facilities associated with producing other products (e.g. domestic gas, condensate, LPG, sulphur, power export) to the extent required to allocate GHG emissions to the different products.
— all GHG emissions associated with producing LNG. These emissions spread across scope 1, scope 2 and scope 3 of the responsible organization. Scope 1, 2 and 3 are defined in this document. All emissions sources are covered including flaring, combustion, cold vents, process vents, fugitive leaks and emissions associated with imported energy.
The LNG plant is considered “under operation”, including emissions associated with initial start-up, maintenance, turnaround and restarts after maintenance or upset. The construction, commissioning, extension and decommissioning phases are excluded from this document but can be assessed separately.
The emissions resulting from boil-off gas management during loading of the ship or any export vehicle are covered by this document. The emissions from a ship at berth, e.g. mast venting are not covered by this document.
This document describes the allocation of GHG emissions to LNG and other hydrocarbon products where other products are produced (e.g. LPG, domestic gas, condensates, sulphur, etc.).
This document defines preferred units of measurement and necessary conversions.
This document also recommends instrumentation and estimations methods to monitor and report GHG emissions. Some emissions are measured and some are estimated.
This document is applicable to the LNG industry.
Applications include the provision of method to calculate GHG emissions through a standardized and auditable method, a means to determine their carbon footprint.
- Standard39 pagesEnglish languagee-Library read for1 day
This document specifies requirements and gives recommendations for the pre-installation surveys, design, materials, equipment, installation, commissioning, operation, inspection, and maintenance of cathodic protection systems for the external surface of on-land pipelines.
This document is applicable to on-land pipelines and piping systems used in other industries and transporting other media such as industrial gases, waters, or slurries.
Throughout this document, on-land pipelines mean:
pipelines that are buried;
landfalls of offshore pipeline sections protected by onshore based cathodic protection installations;
immersed sections of on-land pipelines such as river or lake crossings.
This document is applicable to pipelines of carbon steel, stainless steel, cast iron, galvanized steel, and copper.
This document does not apply to pipelines made of reinforced concrete (see ISO 12696).
- Standard94 pagesEnglish languagee-Library read for1 day
This document specifies the minimum requirements for the contents of the user manual for Automotive LPG propulsion systems fitted in road vehicles.
This document does not cover the user manual for forklift trucks or other industrial machinery.
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This document defines terms as used in the ISO 18101 series that apply to the domain of asset-intensive industry interoperability.
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This document specifies the methodology for the design, planning, and execution of an interlaboratory study (ILS) and calculation of precision estimates of a test method specified by the study. In particular:
it defines the relevant statistical terms,
it specifies the procedures to be adopted in the planning and execution of an ILS to determine the precision of a test method, and
it specifies the method of calculating the precision from the results of such a study.
The procedures in this document have been designed specifically for petroleum and petroleum related products, which are normally considered as homogeneous. However, the procedures described in this document can also be applied to other types of homogeneous products.
- Standard84 pagesEnglish languagee-Library read for1 day
This document describes methods for the determination of sulfur and chlorine content in solid biofuels and pyrogenic biocarbon and specifies two methods for decomposition of the fuel and different analytical techniques for the quantification of the elements in the decomposition solutions. The determination of other elements such as fluorine and bromine are also possible with the methods in this document, however performance data for these elements are not provided. The use of automatic equipment is also included in this document, provided that a validation is carried out as specified and that the performance characteristics are similar to those of the method described in this document.
- Standard18 pagesEnglish languagee-Library read for1 day
This document specifies the methodology for applying precision estimates of a test method derived from the processes specified in ISO 4259-1. In particular, it specifies the procedures for setting the property specification limits based upon test method precision where the property is determined using a specific test method, and determines the specification conformance status when there are conflicting results between supplier and receiver. Other applications of this test method precision are briefly described in principle without the associated procedures.
The procedures in this document have been designed specifically for petroleum and petroleum-related products, which are normally homogeneous. However, the procedures described in this document can also be applied to other types of homogeneous products.
This document is not applicable to non-homogenous products.
- Standard29 pagesEnglish languagee-Library read for1 day
This document specifies requirements and test methods for pipes and fittings which are part of piping systems for the rehabilitation, by means of renovation and trenchless replacement, of underground gas supply networks. It is applicable to polyethylene (PE) pipes, fittings and assemblies, as manufactured and as installed. It is not applicable to the existing pipeline. This document is applicable to the following technique families for renovation, intended to be used at an operating temperature of 20 °C as a reference temperature: lining with continuous pipes; lining with close-fit pipes. This document is applicable to the following technique families for trenchless replacement, intended to be used at an operating temperature of 20 °C as a reference temperature: pipe bursting and pipe extraction; horizontal directional drilling and impact moling. This document is applicable to: PE solid wall single layered pipes (nominal outside diameter, dn), including any identification stripes; PE pipes with co-extruded layers on either or both the outside and inside of the pipe (total outside diameter, dn), as specified in Annex D, where all layers have the same minimum required strength (MRS) rating. Furthermore, when used with lining with continuous pipes and trenchless replacement, this document is applicable to: PE coated pipes (outside diameter, dn) having a peelable, contiguous, thermoplastics additional layer on the outside of the pipe (“coated pipe”), as specified in Annex D. NOTE When used with lining with close-fit lining pipes, the lining pipe is reduced in the factory or on site to provide a close-fitting independent or interactive pressure pipe liner. This document is applicable to jointing by means of butt fusion and electrofusion and to fabricated and injection-moulded fittings and mechanical connections of PE. This document is not applicable to push-fit jointed discrete pipes assembled as part of the trenchless installation process.
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This document specifies a gas chromatographic method for ethanol, in which higher alcohols (propan-1-ol, butan-1-ol, butan-2-ol, 2-methylpropan-1-ol (iso-butanol), 2-methylbutan-1-ol, and 3-methylbutan-1-ol) from (0,1 up to 2,5) mass percentage, methanol from (0,1 up to 3) mass percentage and other impurities, in the range from (0,1 up to 2) mass percentage are determined.
NOTE 1 The European ethanol blending component specification [1] sets a limit for the combined result of ethanol + higher alcohols, not the ethanol content itself.
The method is developed for non-denatured ethanol samples. With sufficient attention to correct separation of the higher alcohols and other components, determination of hydrocarbons in ethanol that contains denaturants as per EN 15376 [1] is possible.
NOTE 2 For the purposes of this document, the term “% (m/m)” is used to represent the mass percentage or mass fraction (ω).
- Standard22 pagesEnglish languagee-Library read for1 day
This document specifies requirements and guidance for production assurance and reliability management as applicable to the assets and operations associated with exploration drilling, exploitation, processing and transport of petroleum, petrochemical and natural gas resources. It covers the assets and associated activities for upstream, midstream, downstream and petrochemical business categories. It focuses on the production assurance of oil and gas with respect to production and associated activities and covers the analysis of reliability and maintenance of the equipment. This includes a variety of associated systems and equipment in the oil and gas value chain. Production assurance addresses not only hydrocarbon production, but also associated activities such as drilling, pipeline installation and subsea intervention.
The document also supports production assurance and reliability management for lower carbon energy assets and associated operations, e.g. carbon capture and storage (CCS), hydrogen, ammonia, and wind energy. It describes the processes, activities, requirements and guidelines for systematic management, effective planning, execution and use of production assurance and reliability technology.
This document defines 12 processes, of which seven are denoted as core production assurance processes and addressed in this document. The remaining five processes are denoted as interacting processes and while they are outside the scope of this document, information is provided as to how they relate to production assurance and reliability management. The relationship of the core production assurance processes with these interacting processes, however, is within the scope of this document as the flow of information to and from these latter processes is required to ensure that production assurance requirements are fulfilled.
The document specifies how to establish and execute a production assurance programme (PAP) and a reliability management programme (RMP).
This document lists processes and activities that can be initiated to add value for the stakeholder (e.g. operator), where the selected process can depend on their business strategy and application area.
This document is intended for the following users and associated activities by their personnel:
Operators: Production assurance and reliability management activities. Related activities include project management and control, technology development, technology qualification, concept and system design, risk management (including HSE), integrity management, and maintenance management.
Contractors: Activities by the main contractor for engineering, procurement, construction, drilling, installation, operation, maintenance services, etc.
Vendors: Activities by manufacturer or supplier related to equipment design and quality management, technology development and qualification.
Authorities: Activities by regulatory bodies to ensure HSE, resource utilization and economic efficiency in operations.
Consultants: Consultancy services aimed at supporting production assurance and reliability management.
Universities: Activities associated with educating industry professionals, as well as conducting fundamental or applied research projects, when related to production assurance, reliability management, and technology development. This includes improvement of the methods and frameworks described herein.
Research institutions: Research activities related to production assurance, reliability management, and technology development. This includes equipment qualification testing and advanced engineering assessments using the methods and frameworks described herein.
- Standard112 pagesEnglish languagee-Library read for1 day
This document specifies methodologies for: the design, analysis and evaluation of stationkeeping systems for floating offshore structures; the assessment of stationkeeping systems for site-specific applications of mobile offshore units and construction units. Originally developed for floating structures used in the oil and gas industry, this document is now also used in the renewable energy sector. The extent of application of this document to floating structures used in other industries is at the discretion of the relevant standard entity and its users. For example, IEC 61400-3-2 for floating wind applies this document to determine stationkeeping system responses while incorporating its own load conditions, safety factors, and environmental return periods. This document is applicable to the following types of stationkeeping systems, which are either covered directly in this document or through reference to other guidelines: spread mooring systems; single point mooring systems; dynamic positioning systems; thruster-assisted mooring systems. This document is not applicable to: stationkeeping systems which do not have redundancy against failure of any single component, e.g., single anchor leg moorings (SALMs); stationkeeping systems which use any means other than mooring lines or thrusters such as tower soft yoke systems, or tension leg platforms (TLPs) that use tendons. The requirements for this document address spread mooring systems and single point mooring systems with mooring lines composed of steel chain, steel wire or synthetic fibre rope. This document is applicable to all aspects of the life cycle of mooring systems. It includes requirements relating to the selection of mooring components, mooring system configuration and performance, components design, installation, post-installation survey, and as-installed assessments as needed for mooring integrity management. For mooring systems deployed in ice-prone environments, additional requirements in ISO 19906 apply.
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This document contains requirements for seismic design and assessment of offshore structures. This document includes recommendations for the effects of seismic events on floating structures. This document addresses specifically the design and assessment of offshore structures subjected to earthquake-induced ground motions. It also covers briefly other geologically induced hazards such as liquefaction, slope instability, fault surface displacement, tsunamis, mud volcanoes and shock waves. This document provides requirements for site-specific probabilistic seismic hazard analysis for offshore structures in high seismic areas and for offshore structures with high consequence levels.
- Standard97 pagesEnglish languagesale 15% off
- Draft111 pagesFrench languagesale 15% off
This document specifies requirements and gives recommendations for the pre-installation surveys, design, materials, equipment, installation, commissioning, operation, inspection, and maintenance of cathodic protection systems for the external surface of on-land pipelines. This document is applicable to on-land pipelines and piping systems used in other industries and transporting other media such as industrial gases, waters, or slurries. Throughout this document, on-land pipelines mean: pipelines that are buried; landfalls of offshore pipeline sections protected by onshore based cathodic protection installations; immersed sections of on-land pipelines such as river or lake crossings. This document is applicable to pipelines of carbon steel, stainless steel, cast iron, galvanized steel, and copper. This document does not apply to pipelines made of reinforced concrete (see ISO 12696).
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This document specifies an ultraviolet (UV) fluorescence test method for the determination of the sulfur content of the following products: having sulfur contents in the range 3 mg/kg to 500 mg/kg: motor gasolines containing up to a mass fraction of 3,7 % (3,7 % (m/m)) of oxygen [including those blended with a volume fraction of ethanol up to about 10 % (10 % (V/V))]; diesel fuels, including those containing up to a volume fraction of about 50 % of fatty acid methyl ester (FAME); having sulfur contents in the range of 3 mg/kg to 45 mg/kg: synthetic fuels, such as hydrotreated vegetable oil (HVO) and gas to liquid (GTL); having sulfur contents in the range of 3 mg/kg to 30 mg/kg: neat FAME (B100) and diesel fuels containing volume fraction of more than 50 % of FAME. Other products (for example process feeds and effluents) can be analysed and other sulfur contents can be determined according to this test method, however, no precision data for products other than automotive fuels and for results outside the specified range have been established for this document. Halogens interfere with this detection technique at concentrations above approximately 3 500 mg/kg.
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This document specifies the standard cost coding system (SCCS) that classifies costs, work hours and quantities for the assets and operations associated with the oil and gas industries including lower carbon energy activities. This document covers all life cycle phases of the assets and operations.
The SCCS is applicable to:
cost estimation;
benchmarking;
cost monitoring and reporting;
collection of quantities, work hours and cost data;
exchange of cost data among organizations;
implementation in cost systems.
This document also provides a basis for the establishment of:
cost classification relevant to cost accounting rules, specific contractual agreements, local requirements for cost reporting to national bodies, government rules and tax regulations, authorization for expenditure, billing purposes, etc.;
unique project breakdown structures (e.g. work breakdown structures, contract breakdown structures and organizational breakdown structures) or asset breakdown structures (e.g. tag or system codes and area or module breakdown structures).
This document is intended for the following users:
operators or owners;
contractors;
vendors, manufacturers or suppliers;
authorities or regulatory bodies;
benchmarking companies;
consultants.
- Standard21 pagesEnglish languagee-Library read for1 day
This document provides general principles, requirements and recommendations for the assessment of the stability of thermoset materials that include short fibre filled or particle filled resins and exclude continuous fibre reinforced composites for service in equipment used in oil and gas exploration and production environments. These procedures can be adapted for application within low-carbon energy environments. This document also provides guidance for quality assurance. This document addresses the resistance of thermosets to the deterioration in properties that can be caused by physical or chemical interaction with produced and injected oil and gas-field media, and with chemical treatment. Interaction with sunlight and ionizing radiation are excluded from the scope of this document. This document is not necessarily applicable to equipment used in refining or downstream processes and equipment. The equipment considered includes, but is not limited to, non-metallic pipelines, piping, liners, seals, gaskets and washers. Applications for short-term exposure include pump-down plugs, bridge plug components, line wiper plugs, balls, setting tools and fracking tools. Applications for long-term exposure include bearings and washers. This document excludes tubular products, tanks and similar items produced from continuous fibre reinforced materials. Blistering by rapid gas decompression is not included in the scope of this document. This document applies to the assessment of the stability of thermoset materials in simulated hydrocarbon production conditions to aid the selection of materials for equipment designed and constructed using conventional design criteria. Designs utilizing other criteria are excluded from the scope of this document.
- Standard37 pagesEnglish languagesale 15% off
- Standard39 pagesFrench languagesale 15% off
This document specifies requirements and guidance for production assurance and reliability management as applicable to the assets and operations associated with exploration drilling, exploitation, processing and transport of petroleum, petrochemical and natural gas resources. It covers the assets and associated activities for upstream, midstream, downstream and petrochemical business categories. It focuses on the production assurance of oil and gas with respect to production and associated activities and covers the analysis of reliability and maintenance of the equipment. This includes a variety of associated systems and equipment in the oil and gas value chain. Production assurance addresses not only hydrocarbon production, but also associated activities such as drilling, pipeline installation and subsea intervention.
The document also supports production assurance and reliability management for lower carbon energy assets and associated operations, e.g. carbon capture and storage (CCS), hydrogen, ammonia, and wind energy. It describes the processes, activities, requirements and guidelines for systematic management, effective planning, execution and use of production assurance and reliability technology.
This document defines 12 processes, of which seven are denoted as core production assurance processes and addressed in this document. The remaining five processes are denoted as interacting processes and while they are outside the scope of this document, information is provided as to how they relate to production assurance and reliability management. The relationship of the core production assurance processes with these interacting processes, however, is within the scope of this document as the flow of information to and from these latter processes is required to ensure that production assurance requirements are fulfilled.
The document specifies how to establish and execute a production assurance programme (PAP) and a reliability management programme (RMP).
This document lists processes and activities that can be initiated to add value for the stakeholder (e.g. operator), where the selected process can depend on their business strategy and application area.
This document is intended for the following users and associated activities by their personnel:
Operators: Production assurance and reliability management activities. Related activities include project management and control, technology development, technology qualification, concept and system design, risk management (including HSE), integrity management, and maintenance management.
Contractors: Activities by the main contractor for engineering, procurement, construction, drilling, installation, operation, maintenance services, etc.
Vendors: Activities by manufacturer or supplier related to equipment design and quality management, technology development and qualification.
Authorities: Activities by regulatory bodies to ensure HSE, resource utilization and economic efficiency in operations.
Consultants: Consultancy services aimed at supporting production assurance and reliability management.
Universities: Activities associated with educating industry professionals, as well as conducting fundamental or applied research projects, when related to production assurance, reliability management, and technology development. This includes improvement of the methods and frameworks described herein.
Research institutions: Research activities related to production assurance, reliability management, and technology development. This includes equipment qualification testing and advanced engineering assessments using the methods and frameworks described herein.
- Standard112 pagesEnglish languagee-Library read for1 day
This document specifies a method for the determination of the softening point of bitumens and bituminous binders in the range of 28 °C to 150 °C.
The method described is also applicable to bituminous binders that have been recovered from bituminous mixes, e.g. by extraction according to EN 12697-3 [1].
WARNING — The use of this document can involve hazardous materials, operations and equipment. This document does not purport to address all of the safety problems associated with its use. It is the responsibility of the user of this document to establish appropriate safety and health practices and to determine the applicability of regulatory limitations prior to use.
- Standard33 pagesEnglish languagee-Library read for1 day
This document specifies the methodology for applying precision estimates of a test method derived from the processes specified in ISO 4259-1. In particular, it specifies the procedures for setting the property specification limits based upon test method precision where the property is determined using a specific test method, and determines the specification conformance status when there are conflicting results between supplier and receiver. Other applications of this test method precision are briefly described in principle without the associated procedures.
The procedures in this document have been designed specifically for petroleum and petroleum-related products, which are normally homogeneous. However, the procedures described in this document can also be applied to other types of homogeneous products.
This document is not applicable to non-homogenous products.
- Standard29 pagesEnglish languagee-Library read for1 day
This document describes methods for the determination of sulfur and chlorine content in solid biofuels and pyrogenic biocarbon and specifies two methods for decomposition of the fuel and different analytical techniques for the quantification of the elements in the decomposition solutions. The determination of other elements such as fluorine and bromine are also possible with the methods in this document, however performance data for these elements are not provided. The use of automatic equipment is also included in this document, provided that a validation is carried out as specified and that the performance characteristics are similar to those of the method described in this document.
- Standard18 pagesEnglish languagee-Library read for1 day
This document specifies requirements and guidance for production assurance and reliability management as applicable to the assets and operations associated with exploration drilling, exploitation, processing and transport of petroleum, petrochemical and natural gas resources. It covers the assets and associated activities for upstream, midstream, downstream and petrochemical business categories. It focuses on the production assurance of oil and gas with respect to production and associated activities and covers the analysis of reliability and maintenance of the equipment. This includes a variety of associated systems and equipment in the oil and gas value chain. Production assurance addresses not only hydrocarbon production, but also associated activities such as drilling, pipeline installation and subsea intervention. The document also supports production assurance and reliability management for lower carbon energy assets and associated operations, e.g. carbon capture and storage (CCS), hydrogen, ammonia, and wind energy. It describes the processes, activities, requirements and guidelines for systematic management, effective planning, execution and use of production assurance and reliability technology. This document defines 12 processes, of which seven are denoted as core production assurance processes and addressed in this document. The remaining five processes are denoted as interacting processes and while they are outside the scope of this document, information is provided as to how they relate to production assurance and reliability management. The relationship of the core production assurance processes with these interacting processes, however, is within the scope of this document as the flow of information to and from these latter processes is required to ensure that production assurance requirements are fulfilled. The document specifies how to establish and execute a production assurance programme (PAP) and a reliability management programme (RMP). This document lists processes and activities that can be initiated to add value for the stakeholder (e.g. operator), where the selected process can depend on their business strategy and application area. This document is intended for the following users and associated activities by their personnel: Operators: Production assurance and reliability management activities. Related activities include project management and control, technology development, technology qualification, concept and system design, risk management (including HSE), integrity management, and maintenance management. Contractors: Activities by the main contractor for engineering, procurement, construction, drilling, installation, operation, maintenance services, etc. Vendors: Activities by manufacturer or supplier related to equipment design and quality management, technology development and qualification. Authorities: Activities by regulatory bodies to ensure HSE, resource utilization and economic efficiency in operations. Consultants: Consultancy services aimed at supporting production assurance and reliability management. Universities: Activities associated with educating industry professionals, as well as conducting fundamental or applied research projects, when related to production assurance, reliability management, and technology development. This includes improvement of the methods and frameworks described herein. Research institutions: Research activities related to production assurance, reliability management, and technology development. This includes equipment qualification testing and advanced engineering assessments using the methods and frameworks described herein.
- Standard104 pagesEnglish languagesale 15% off
- Standard110 pagesFrench languagesale 15% off
This document specifies the methodology for the design, planning, and execution of an interlaboratory study (ILS) and calculation of precision estimates of a test method specified by the study. In particular:
it defines the relevant statistical terms,
it specifies the procedures to be adopted in the planning and execution of an ILS to determine the precision of a test method, and
it specifies the method of calculating the precision from the results of such a study.
The procedures in this document have been designed specifically for petroleum and petroleum related products, which are normally considered as homogeneous. However, the procedures described in this document can also be applied to other types of homogeneous products.
- Standard84 pagesEnglish languagee-Library read for1 day