Petroleum och motsvarande tekniker

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.

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.

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.

This document describes technical measures to be carried out at crossings and parallelisms of buried metal pipelines influenced by systems. It provides guidance on how the design, construction, operation, maintenance, and decommissioning phases of systems affect buried metal pipelines. Electromagnetic, DC interference and thermal influences on pipeline coatings are described.

Acceptable levels of interference are discussed.

Guidance is provided for calculation methods to establish an acceptable separation distance between the pipeline and the source of interference.

The following aspects are not covered in this document:

Interference from other AC sources

Contractual responsibilities

Personnel safety.

This document specifies requirements and test methods for organic compounds suitable for odorization of fuel gases hereafter referred to as odorants. This document applies to fuel gases: natural gas, natural gas substitutes such as biomethane, mixtures of natural gas with a volume fraction of hydrogen up to 20 %.

This document specifies requirements and gives recommendations for 8 classes of well cements, including their chemical and physical requirements and procedures for physical testing. This part of ISO 10426 is applicable to well cement classes A, B, C and D, which are the products obtained by grinding Portland cement clinker and, if needed, calcium sulfate as an interground additive. Processing additives can be used in the manufacture of cement of these classes. Suitable set-modifying agents can be interground or blended during manufacture of class D cement. This part of ISO 10426 is also applicable to well cement classes G and H, which are the products obtained by grinding clinker with no additives other than one or more forms of calcium sulfate, water or chemical additives as required for chromium (VI) reduction. This part of ISO 10426 is also applicable to composite well cements classes K and L, which are the products obtained by intergrinding Portland cement clinker and one or more forms of CaSO4 with specified composite constituents, or by subsequent blending of separately produced Portland cement with separately processed specified composite constituents. This document is a supplement to API Spec 10A 25th edition (2019) and its Addendum 1 (November 2019) and Addendum 2 (August 2022), the requirements of which are applicable with the exceptions specified in this document.

This document specifies requirements and test methods for marketed and delivered automotive B10 diesel fuel, i.e. diesel fuel containing up to 10,0 %(V/V) fatty acid methyl ester (FAME). It is applicable to fuel for use in diesel engine vehicles compatible with automotive B10 diesel fuel. NOTE 1 This product is allowed in Europe [4], but national legislation can set additional requirements or rules concerning, or even prohibiting, marketing or delivering of the product. NOTE 2 For the purposes of this document, the terms "% (m/m)" and "% (V/V)" are used to represent respectively the mass fraction and the volume fraction.

This document specifies a general method of using a dynamic shear rheometer (DSR) for measuring the rheological properties of bituminous binders. The procedure involves determining the complex shear modulus and phase angle of binders over a range of test frequencies and test temperatures when tested in oscillatory shear. From the test, the complex shear modulus, |G*|, and its phase angle, δ, at a given temperature and frequency are calculated, as well as the components G' and G" of the complex shear modulus. This method is applicable to un-aged, aged, stabilized and recovered bituminous binders. The test procedure in accordance with this document is not applicable for bituminous binders with particles larger than 250 μm (e.g. filler material, granulated rubber). 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.

This document specifies the Binder Fast Characterization Test (for short: BTSV test, German: Bitumen-Typisierungs-Schnell-Verfahren). The test is conducted using a Dynamic Shear Rheometer (DSR). It is used to characterize bitumen and bituminous binders and to assess the deformation behaviour at high service temperatures. The test procedure described in this document covers the testing of paving grade bitumen or modified bitumen, as fresh (unused) binders, as well as binders after laboratory ageing conditioning (e.g. EN 12607-1, EN 14769), and also binders that have been recovered from asphalt mixtures. The test procedure in accordance with this document is not applicable for bituminous binders with particles larger than 250 μm (e.g. filler material, granulated rubber). NOTE The test procedure has not been applied on bituminous binders recovered from bitumen emulsions yet. The test determines the temperature and the associated phase angle at which a bituminous binder exhibits a defined complex shear modulus in stress-controlled oscillation mode at constant frequency and with continuous increase of the test temperature. 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 ensure that regulatory requirements are fulfilled prior to application of this document. This document involves handling of apparatus and binders at very high temperatures. Always wear protective gloves and eyewear when handling hot binders, and avoid contact with any exposed, unprotected skin.

This document provides testing procedures for evaluating proppants used in hydraulic fracturing and gravel packing operations. NOTE Proppants mentioned in this document refer to sand, ceramic, resin-coated, gravel packing proppants, and other materials used for hydraulic fracturing and gravel packing operations. This document supplements API RP 19D, 2nd edition (2021), the requirements of which are applicable with the exceptions specified in this document. This document provides consistent methodology for testing performed on hydraulic fracturing and/or gravel packing proppants. It is not intended for use in obtaining absolute values of proppant pack conductivities under downhole reservoir conditions.

This document specifies requirements for surface preparation, materials, application, inspection and testing of internal coating lining systems that are intended to be applied on internal surfaces of steel storage tanks of crude oil, hydrocarbons and water for corrosion protection. It covers both new construction and maintenance works of tank internal coating and lining as well as the repair of defective and deteriorated coating/lining. This document also provides requirements for shop performance testing of the coated/lined samples and the criteria for their approval.

This document specifies a test method for continuous process analysis (real-time analysis) using near-infrared spectroscopy for the indirect determination of the following fuel-characterising parameters:

— total chlorine content;

— water content;

— heating value.

NOTE When accuracy is proven, real-time analysis can be supplemented by further fuel-characterising parameters.

This document applies to solid recovered fuels according to ISO 21640.