Standards

The fieldbus data link layer provide basic time-critical messaging communication between devices in an automation environment. The purpose of this part of IEC 61158 is to define eight distinct and non- interoperable fieldbus Data link protocols. Each protocol defined in this standard is most most closely related to and lies within the field of application of the corresponding services of IEC 61158-3. the fieldbus data link services definition .

This part of IEC 61850 specifies the specific communication service mappings for the communication between bay and process level and if specifies a mapping on a serial unidirectional multidrop point point to point link in accordance with IEC 60044-8. This part of IEC 61850 specifies a mapping of the abstract service for the transmission of sampled values ( as defined in IEC 61850-7-2 ) on a serial unidirectional multidrop point link in accordance with IEC 60044-8. It applies to the communication between merging units of electronic current (ECT) or voltage-transformers (EVT) and bay devices such as protection relays. If higher requirements on sampling rate. further sampling measured value data sets in addition to the universal data set. inter-bay communication and synchronization apply, these will be covered by IEC 61850-9-2 Figure 1 show the schematics of this interface.

This part of IEC defines the specific communication services mapping (SCSM) for the transmission of sampled values according to the abstract specification in IEC 61850-7-2. The mapping is that of the abstract model on a mixed stack using access to an ISO/IEC 8802-3 link for the transmission of the samples in combination with IEC 61850-8-1.

This part of the ISO/IEC 9314 specifies the Media access control (MAC) the middle sublayer of the data link layer (DLL) for fiber distributed data interface (FDD). FDDI (ISO/IEC 9314) provides a high- bandwidth (100 Mbits) general - purpose interconnection among information processing systems, subsystems and peripheral equipment, using fiber optics or other transmission media. (FDDI can be configured to support a sustained data transfer rate of at least 80 Mbits/s (10 Mbyte/s). FDDI provides connectively for many nodes distributed over distances of many kilometers in extent. Certain default parameter values for FDDI (eg. timer settings) are calculated on the basis of up to 1000 transmission links or up to 200 km total fiber path length (typically corresponding to 500 nodes and 100 km of dual fiber cable, respectively) however, the FDDI protocols can support much larger networks by increasing these parameter values.

This International standard defines an input/output bus for interconnecting computers and peripheral devices. It defines extensions to the small computer system interface (ISO 9316:1989), referred to herein to herein as SCSI-1. Its also provides more complete standardization of the previously characteristics of the interface to allow inter-operability of conforming devices. This International standards is referred to herein as SCS1-2. The term SCS1 is used wherever it is not necessary between the two version

This document establishes requirements and provides guidelines for subsurface safety valve (SSSV) system equipment. This includes requirements for SSSV system design, installation, operation, testing, redress, support activities, documentation, and failure reporting. SSSV system equipment addressed by this document includes control systems, control lines, SSSVs, and secondary tools as defined herein. SSSV types including surface controlled (SCSSV), sub-surface controlled (SSCSV), and sub-surface injection safety valves (SSISV) are included. Requirements for testing of SSSVs including frequency and acceptance criteria are included. Alternate technology SSSV equipment and systems are included in these requirements. This document is not applicable to design, qualification, or repair activities for SSSVs. This document does not specify when a SSSV is required. 

This standard can be purchase via the American Petroleum Institute (API) website www.api.org 

1 Scope 1.1 Coverage The purpose of this document is to recommend practices and procedures for promoting and maintaining safe and healthy working conditions for personnel in drilling and well servicing operations.

1.2 Applicability These recommendations apply to rotary drilling rigs, well servicing rigs, and special services as they relate to operations on location. It is intended that the applicable requirements and recommendations of some sections of the document be applied, as appropriate, to other sections. The recommendations are not intended to cover seismic drilling or water well drilling operations. These recommendations do not apply to site preparation and site remediation operations.

1.3 Responsibility Employers have the responsibility to identify, communicate, and mitigate hazards at the work site. A process of risk assessment may be an effective method to protect employees at the work site.

This standard can be purchase via the American Petroleum Institute (API) website www.api.org 

This recommended practice (RP) provides guidance for floating system integrity management (FSIM) of floating production systems (FPSs), which include tension leg platforms (TLPs), used by the petroleum and natural gas industries to support drilling, production, storage, and/or offloading operations.

FPSs described in this RP are governed by local regulatory requirements and recognized classification society (RCS) rules (if classed). No specific regulatory compliance or RCS requirements are restated in this RP. The requirements of this RP do not apply to mobile offshore drilling units (MODUs) or to mobile offshore units (MOUs) used in support of construction operations. For integrity management (IM) considerations, these units are typically governed by RCS rules, and include, among others:

— floating systems intended primarily to perform drilling and/or well intervention operations even when used for extended well test operations;

— floating systems used for offshore construction operations (e.g. crane barges or pipelay barges), for temporary or permanent offshore living quarters, or for transport of equipment or products (e.g. transportation barges, cargo barges); for these, see appropriate RPs.

This RP does not address moorings or risers; these are addressed separately by API 2MIM and API 2RIM, respectively. Dynamic positioning is not covered in this RP.

The following types of floating systems are explicitly covered by this RP:

— ship-shaped floating systems and barges (monohull or otherwise);

— semisubmersibles;

— spars;

— tension leg platforms (TLPs), including tendon systems.

The following types of floating system components are included within the context of this RP:

— hull structure, including above water, below water, and internal (i.e. hull compartments) structure and corrosion protection systems (e.g., coatings, cathodic potential, etc.);

— structural systems, such as turrets, topsides structure, helidecks, flares, cranes, and process decks, and their interfaces with the hull structure;

— mooring system support structure on the hull (e.g. foundations for chain jacks, fairleads, chain stoppers, etc.)

— tendon systems, including foundations;

— marine systems, such as ballast, bilge, venting, soundings, firefighting systems, cargo systems, emergency power, propulsion, steering, sensors, alarms, and controls (vessels in transit are not included);

— permanent means of access and egress, including walkways, grating, handrails;

— structural interfaces between hull structure and riser system;

— appurtenances;

— life safety appliances.

This RP is directly applicable to oil and gas producing floating systems operating at ambient temperature, including floating liquefied natural gas (FLNG) plants, except for the aspects related to handling and storage of cryogenic liquids.

The FSIM process provided in this RP is applicable to floating systems installed at any location worldwide. However, the referenced metocean criteria has regional limitations.

This standard can be purchase via the American Petroleum Institute (API) website www.api.org 

This standard provides requirements for the installation and testing of blowout prevention equipment systems on land and marine drilling rigs (barge, platform, bottom-supported, and floating). This includes but is not limited to: BOPs (blowout preventers), Choke and kill lines, Choke and manifolds, Control systems, Auxiliary equipment. The primary functions of these systems are to confine well fluids to the wellbore, provide means to add fluid to the wellbore, and allow controlled volumes to be removed from the wellbore.

This standard does not apply to: Diverters, shut-in devices, and rotating head systems, as these systems are designed to safely divert or direct flow rather than to confine fluids to the well bore.

This standard is intended to be used together with API RP 59.

This standard can be purchase via the American Petroleum Institute (API) https://www.apiwebstore.org/standards/53 

This document provides guidance for managing annular casing pressure on offshore wells of various types to ensure that well integrity is maintained, and risks are managed

This document is meant to be used for existing offshore wells that exhibit annular casing pressure, including thermally induced casing pressure, sustained casing pressure (SCP) and operator-imposed pressure. It contains general information regarding annular casing pressure that is applicable to all offshore well types: fixed platform wells, subsea wells, hybrid wells and mudline suspension wells.

This standard can be purchase via the American Petroleum Institute (API) https://www.apiwebstore.org/standards/90-1