Petroleum och motsvarande tekniker

This international standard defines a method of determining bulk density of solid recovered fuels by the use of a standard measuring container.

This document specifies the requirements for two types of rubber hoses and rubber hose assemblies for loading and discharge of liquid hydrocarbon fuels with a maximum working pressure of 10 bar (1,0 MPa). Both types of hose are designed for: a) use with hydrocarbon fuels, having an aromatic hydrocarbon content not exceeding 50 % by volume and containing oxygenated compounds up to 15 %; b) operation within the temperature range of −30 °C to +70 °C, undamaged by climatic conditions of −50 °C to 70 °C when stored in static conditions. This document is not applicable to hoses and hose assemblies for LPG, aviation fuel systems, fuel station systems and marine applications.

This document specifies a method for the calibration of spherical tanks with radius greater than 1m by means of external measurements using an electro-optical distance-ranging (EODR) instrument.

This document contains requirements for defining the seismic design procedures and criteria for offshore structures; guidance on the requirements is included in Annex A. The requirements focus on fixed steel offshore structures and fixed concrete offshore structures. The effects of seismic events on floating structures and partially buoyant structures are briefly discussed. The site-specific assessment of jack-ups in elevated condition is only covered in this document to the extent that the requirements are applicable. Only earthquake-induced ground motions are addressed in detail. Other geologically induced hazards such as liquefaction, slope instability, faults, tsunamis, mud volcanoes and shock waves are mentioned and briefly discussed. The requirements are intended to reduce risks to persons, the environment, and assets to the lowest levels that are reasonably practicable. This intent is achieved by using: a) seismic design procedures which are dependent on the exposure level of the offshore structure and the expected intensity of seismic events; b) a two-level seismic design check in which the structure is designed to the ultimate limit state (ULS) for strength and stiffness and then checked to abnormal environmental events or the abnormal limit state (ALS) to ensure that it meets reserve strength and energy dissipation requirements. Procedures and requirements for a site-specific probabilistic seismic hazard analysis (PSHA) are addressed for offshore structures in high seismic areas and/or with high exposure levels. However, a thorough explanation of PSHA procedures is not included. Where a simplified design approach is allowed, worldwide offshore maps, which are included in Annex B, show the intensity of ground shaking corresponding to a return period of 1 000 years. In such cases, these maps can be used with corresponding scale factors to determine appropriate seismic actions for the design of a structure, unless more detailed information is available from local code or site-specific study. NOTE     For design of fixed steel offshore structures, further specific requirements and recommended values of design parameters (e.g. partial action and resistance factors) are included in ISO 19902, while those for fixed concrete offshore structures are contained in ISO 19903. Seismic requirements for floating structures are contained in ISO 19904, for site-specific assessment of jack-ups and other MOUs in the ISO 19905 series, for arctic structures in ISO 19906 and for topsides structures in ISO 19901‑3.

This standard covers architectural doors applied to topside and living quarter areas for fixed or floating offshore oil and gas projects.

This document is applicable to all wells that are operated by the petroleum and natural gas industry. This document is applicable to any well, or group of wells, regardless of their age, location (including onshore, subsea and offshore wells), function, status or type (e.g. naturally flowing, artificial lift, injection wells). This document is intended to assist the petroleum and natural gas industry to effectively manage well integrity during the well life cycle by providing: — minimum requirements to ensure management of well integrity; and — recommendations and techniques that well operators can apply in a scalable manner based on a well’s specific risk characteristics. Assuring well integrity comprises two main building blocks: the first is to ensure well integrity during well design and construction, and the second is to manage well integrity throughout the remaining well life thereafter. This document addresses each stage of the well life cycle, as defined by the six phases in a) to f), and describes the deliverables between each phase within a Well Integrity Management system. a) The “Basis of Design Phase” identifies the probable safety and environmental exposure to surface and subsurface hazards and risks that can be encountered during the well life cycle. Once identified, these hazards and risks are assessed such that control methods of design and operation can be developed in subsequent phases of the well life cycle. b) The “Design Phase” identifies the controls that are to be incorporated into the well design, such that appropriate barriers can be established to manage the identified safety and environmental hazards. The design addresses the expected, or forecasted, changes during the well life cycle and ensures that the required barriers in the well’s design are based on risk exposure to people and the environment. c) The “Construction Phase” defines the required or recommended elements to be constructed (including rework/repair) and verification tasks to be performed in order to achieve the intended design. It addresses any variations from the design which require a revalidation against the identified hazards and risks. The construction phase typically ends once the well is handed over to the production operations function. d) The “Operational Phase” defines the requirements or recommendations and methods for managing well integrity during operation. This is when typically wells are under the control of operations / production function. e) The “Intervention Phase” (including work-over) defines the minimum requirements or recommendations for assessing well barriers prior to, and after, any well intervention that involves breaking the established well barrier containment system. f) The “Abandonment Phase” defines the requirements or recommendations for permanently abandoning a well. The six phases of the well life cycle (including handover), as defined in this Scope, and their interrelationships, are illustrated in Figure 2 in the Introduction. v This document is not applicable to well control. Well control refers to activities implemented to prevent or mitigate unintentional release of formation fluids from the well to its surroundings during drilling, completion, intervention and well abandonment operations, and involves dynamic elements, i.e. BOPs, mud pumps, mud systems, etc. This document is not applicable to wellbore integrity, sometimes referred to as “borehole stability”. Wellbore integrity is the capacity of the drilled open hole to maintain its shape and remain intact after having been drilled.

This document specifies the requirements for qualification, application, testing and handling of materials for plant application of single layer fusion-bonded epoxy (FBE) coatings applied externally for the corrosion protection of bare steel pipe for use in pipeline transportation systems for the petroleum and natural gas industries as defined in ISO 13623. NOTE Pipes coated in accordance with this document are considered suitable for additional protection by means of cathodic protection.

I detta dokument anges krav på provtagning, tekniska krav, miljökrav, provningsmetoder och beteckning för hydraulvätskor av klass M (utan krav på köldegenskaper) och klass V (med krav på köldegenskaper).

Detta dokument är tillämpbart för den färdiga, oanvända hydraulvätskan, inklusive tillsatsmedel.

Detta dokument omfattar inte svårbrännbara hydraulvätskor.

This document specifies a method for evaluating the change of consistency, as measured by cone penetration, of lubricating grease when worked in the roll stability test apparatus. The method only applies to greases with cone penetration in the range 175 1/10 mm to 385 1/10 mm as measured using ISO 2137.

This document specifies a method for evaluating the change of consistency, as measured by cone penetration, of lubricating grease when worked in the roll stability test apparatus, in presence of water. The method only applies to greases with cone penetration in the range 175 1/10 mm to 385 1/10 mm as measured using ISO 2137.