External Load

External Load

Definition(s)

External Load

Includes global load effects like axial loads, bending moment, torque, and shear.

Source: API Technical Report 17TR7, Verification and Validation of Subsea Connectors, First Edition, April 2017. Global Standards

External Load

There are two types of primary external load, other than environmental load, to which a subsea tree and its upper and lower connectors can be subjected. The first type is installation, which includes riser loads and flowline connection loads. The second type of external load occurs during workover and, depending on the type of tree, can be due to attachment of a C/WO riser system or marine drilling riser system. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards
Subsea System Engineering

Subsea System Engineering

Definition(s)

Subsea system engineering

Subsea system engineering is an interdisciplinary approach which covers the complete system, from the reservoir to the processing facilities on the host (inclusive), with consideration of the requirements of all phases of the development, including engineering, procurement, construction, testing, installation, commissioning, operation, workover/maintenance and abandonment. The system engineering process consists of a management part and a technical part. An evaluation of the need for application of the various system engineering processes should be performed for each specific field development, based upon the characteristics of the development. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  
Flow Assurance

Flow Assurance

Definition(s)

Flow assurance

Flow assurance is a term commonly used to cover a wide range of flow-related issues. These issues typically include: hydrate formation, wax formation, asphaltene formation, emulsions, foaming, scale formation, sand production, slugging, materials-related issues. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  

Flow assurance

Flow assurance is the control or mitigation of the deposition/formation of hydrates, wax, asphaltenes, and scale in the production flow path. Many factors affect flow assurance such as fluid composition, pressure, flow rate and temperature. Fluids in the wellbore can experience significant temperature changes, and plugs can form as a result. Flow assurance is provided by chemical and/or thermal management. Design of the total system should consider the wellhead and tree, which have the highest heat loss. Some methods of prevention used in industry are as follows: VIT; tubing coating or finish; gas-filled “A” annulus near/above the mudline; low heat transfer fluid in the annulus; injection of fluids to minimize/prevent the effects of hydrates, paraffin, scale through “control lines” strapped to the outside of the tubing; placement of SCSSVs below the top of hydrate/wax/asphaltene formation depth. Source: API RP 96, Deepwater Well Design and Construction, First Edition, March 2013. Global Standards
Production Riser

Production Riser

Definition(s)

Production Riser

Casing strings rising from the seafloor to the wellhead (fixed platforms) or casing strings attached to the subsea wellhead rising from seafloor to a surface wellhead (hybrid wells). Source: ISO 16530-1:2017, Petroleum and natural gas industries — Well integrity – Part 1: Life cycle governance, First Edition, March 2017. Global Standards

Production Riser

The portion of a pipeline extending from the seafloor to the surface is termed a riser. The function of a riser is to provide conduit(s) for the conveying of produced fluids and/or injection fluids between the seafloor equipment and the production host. Such risers are generally known as production risers in order to distinguish them from other types of risers such as marine drilling risers and completion/workover risers. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  

Production Riser

The casing string(s) rising from the seafloor to the wellhead on fixed platforms or the casing string(s) attached to the subsea wellhead rising from the seafloor to the surface wellhead on hybrid wells. Source: API RP 90, Annular Casing Pressure Management for Offshore Wells, Upstream Segment. First Edition, August 2006. Global Standards Source: API STD 65 – Part 2, Isolating Potential Flow Zones During Well Construction, Upstream Segment, Second Edition, December 2010. Global Standards
Multiphase Flow

Multiphase Flow

Definition(s)

Multiphase flow

The simultaneous flow of gas and liquid, commonly referred to as multiphase flow, occurs in almost every aspect of the oil industry. Multiphase flow is typically present in the wellbore, flowlines and topsides processing facilties and is of particular importance in subsea production systems, where the feasibility and cost of the production facilities is directly linked to the fluid flow charateristics. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards
Reverse Emulsion

Reverse Emulsion

Definition(s)

Reverse emulsion

Emulsions can be water-in-oil, which are referred to as regular emulsions, as well as oil in-water, which are called reverse emulsions. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  
Regular Emulsion

Regular Emulsion

Definition(s)

Regular emulsion

Emulsions can be water-in-oil, which are referred to as regular emulsions, as well as oil in-water, which are called reverse emulsions. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  
Emulsion

Emulsion

Definition(s)

Emulsion

Emulsions are heterogeneous systems consisting of at least one immiscible liquid dispersed in another in the form of small droplets of diameter usually greater than 0,1 μm. Such systems are thermodynamically unstable but they can be persistent if stabilized by surface-active components. Emulsions can be water-in-oil, which are referred to as regular emulsions, as well as oil in-water, which are called reverse emulsions. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards
Signal on Power

Signal on Power

Definition(s)

Signal on power

Separate electrical cables may also be required for transmission of control signals/data in an electrohydraulic PCS. Alternatively, the control signals/data may be superimposed on the power output, commonly referred to as “signal on power”. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  
Control Pod

Control Pod

Definition(s)

Control pod

Assembly of valves and regulators (either hydraulically or electrically operated) that when activated directs hydraulic fluid through special apertures to operate the BOP equipment.

Source: API Specification 16Q, Design, Selection, Operation, and Maintenance of Marine Drilling Riser Systems, Second Edition, April 2017. Global Standards

Control pod

An assembly of subsea valves and regulators which when activated from the surface will direct hydraulic fluid through special porting to operate BOP equipment. Source: API RP 16Q, Recommended Practice for Design, Selection, Operation and Maintenance of Marine Drilling Riser Systems, First Edition, November 1993 (Reaffirmed August 2001). Global Standards

Subsea control module or control pod

A subsea control module (colloquially referred to as a “control pod”) is normally mounted directly on the facility to be controlled, such as a subsea tree/manifold, on a base from which it can be removed for maintenance if necessary. The control pod is the interface between the control lines, supplying hydraulic and electric power and signals from the host facility, and the subsea equipment to be monitored and controlled. The control pod contains pilot valves powered by hydraulic fluid, electric power or both, that is supplied from the host facility. The pod also contains electronic components that are used for control, communications and data-gathering. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  

Control pod

An assembly of valves and regulators (either hydraulically or electrically operated) that when activated, will direct hydraulic fluid through special apertures to operate the BOP functions. Source: API RP 96, Deepwater Well Design and Construction, First Edition, March 2013. Global Standards  

Control pod

The assemblage of valves and pressure regulators which respond to control signals to direct hydraulic power fluid through assigned porting to operate functions. Source: API SPEC 16D, Specification for Control Systems for Drilling Well Control Equipment and Control Systems for Diverter Equipment, Upstream Segment, Second Edition, July 2004. Global Standards  

Control pod

An assembly of subsea valves and regulators (either hydraulically or electrically operated) that when activated will direct hydraulic fluid through special apertures to operate the BOP equipment. Source: API STD 53, Blowout Prevention Equipment Systems for Drilling Wells, Upstream Segment, Fourth Edition, November 2012. Global Standards  

Control pod

Assembly of subsea valves and regulators that, when activated from the surface, directs hydraulic fluid through special porting to operate BOP equipment. Source: ISO 13624-1:2009, Petroleum and natural gas industries – Drilling and production equipment – Part 1:Design and operation of marine drilling riser equipment. Global Standards  
Subsea Control Module

Subsea Control Module

Definition(s)

Subsea control module or control pod

A subsea control module (colloquially referred to as a “control pod”) is normally mounted directly on the facility to be controlled, such as a subsea tree/manifold, on a base from which it can be removed for maintenance if necessary. The control pod is the interface between the control lines, supplying hydraulic and electric power and signals from the host facility, and the subsea equipment to be monitored and controlled. The control pod contains pilot valves powered by hydraulic fluid, electric power or both, that is supplied from the host facility. The pod also contains electronic components that are used for control, communications and data-gathering. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  
Comms on Power

Comms on Power

Definition(s)

Comms on power

Some electrohydraulic systems superimpose the control signals on the power circuit. This is commonly referred to as “comms on power”, and eliminates the need for a separate communications cable thus reducing umbilical cost. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards
Unitized Template

Unitized Template

Definition(s)

Unitized template

The term “modular” can also be applied to the method of constructing the other components of a template system. For example, a multiwell/manifold template can be described as being modular (even if the well-spacer template was run as a single piece, as the hinged design described above) if the manifold, pigging valve assembly, etc., are installed after the template. The alternative to this type of modularization is installation of a multiwell/manifold template all-in-one-piece/unit. This type of template is often referred to as a unitized template, and a heavy-lift vessel is typically required to install it. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  
Modular

Modular

Definition(s)

Modular

The term “modular” can also be applied to the method of constructing the other components of a template system. For example, a multiwell/manifold template can be described as being modular (even if the well-spacer template was run as a single piece, as the hinged design described above) if the manifold, pigging valve assembly, etc., are installed after the template. The alternative to this type of modularization is installation of a multiwell/manifold template all-in-one-piece/unit. This type of template is often referred to as a unitized template, and a heavy-lift vessel is typically required to install it. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards
Drilling and Production Template

Drilling and Production Template

Definition(s)

Multiwall/manifold template or drilling and production template

A multiwell/manifold template (also often referred to as a drilling and production template) is a template with multiple wells drilled and completed through it, and incorporating a manifold system for gathering of produced fluids and/or distribution of injected fluids, as well as a production riser support is illustrated in Figure A.22. This type of template also includes connection point(s) for tie-in of flowlines or production risers to/from the manifold to the host facility. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards
Multiwall/manifold Template

Multiwall/manifold Template

Definition(s)

Multiwall/manifold template or drilling and production template

A multiwell/manifold template (also often referred to as a drilling and production template) is a template with multiple wells drilled and completed through it, and incorporating a manifold system for gathering of produced fluids and/or distribution of injected fluids, as well as a production riser support is illustrated in Figure A.22. This type of template also includes connection point(s) for tie-in of flowlines or production risers to/from the manifold to the host facility. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards
Template

Template

Definition(s)

Template

It should be noted that the term “template” is also often used to refer to the combined unit, i.e. the template protective structure and the manifold. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  

Template

A template is a seabed-founded structure that consists of a structural framework and a foundation (driven/suction piles or gravity-based), arranged so as to provide support for various subsea equipment such as: subsea wellheads and trees, piping manifolds (for production, injection, well testing and/or chemical distribution systems), control system components, e.g. SCMs, hydraulic piping, electrical cabling, drilling and completion equipment, pipeline pull-in and connection equipment, production risers. A template also often incorporates protective framing and/or covers to protect subsea equipment from impact damage from dropped objects and/or fishing equipment. Depending on the functions templates are designed to serve, they can range in complexity from simple spacer templates to multiwell manifold templates, as defined below, and actual templates may combine features of more than one of these types. It should be noted that the term “template” is also often used to refer to the combined unit, i.e. the template protective structure and the manifold. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  

Template

Procedural guide consisting of equations, test methods and measurements for establishing design performance properties. Source: API TR 5C3, Technical Report on Equations and Calculations for Casing, Tubing, and Line Pipe Used as Casing or Tubing; and Performance Properties Tables for Casing and Tubing, Upstream Segment, First Edition, December 2008. Global Standards  
Subsea Tree System

Subsea Tree System

Definition(s)

Subsea tree system

The equipment required to complete a subsea well for production or injection purposes includes a tubing hanger and a tree, often referred to in combination as the “subsea tree system”. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  
Accidental Load

Accidental Load

Definition(s)

Accidental Load

Load caused by accidental occurrence. Source: API RP 17L2, Recommended Practice for Flexible Pipe Ancillary Equipment, First Edition, March 2013. Global Standards Source: API SPEC 17L1, Specification for Flexible Pipe Ancillary Equipment, First Edition, March 2013. Global Standards  

Accidental Load

Load(s) which are imposed on the C/WO riser system under abnormal and unplanned conditions.
  • EXAMPLES Loss of vessel station-keeping and heave compensator lock-up.
Source: API RP 17G, Recommended Practice for Completion/Workover Risers, Second Edition, July 2006 (Reaffirmed April 2011). Global Standards  

Accidental Load

Accidental loads are loads caused by accidental occurrences. Source: API SPEC 17J, Specification for Unbonded Flexible Pipe, Third Edition, July 2008. Global Standards
Safety

Safety

Definition(s)

Safety

Safety includes all operational, technical and emergency preparations significant for the protection of people, environment, installations and vessels present. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  

Safety

Freedom from those conditions that can cause death, injury, occupational illness, damage to or loss of equipment or property, or damage to the environment. Source: API RP 98, Personal Protective Equipment Selection for Oil Spill Responders, First Edition, August 2013. Global Standards  

Safety

The safety of products, production processes, operation, storage, transportation, sale and reclamation (hereinafter referred to as safety): a condition ruling out the possibility of inadmissible risk associated with harm to be caused to individuals' life or health, a natural person's or legal entity's property, state or municipal property, the environment, to the life or health of animals or plants. Source: Federal Law on Technical Regulation, No. 184-FZ, Russian Federation, December 2002 (amended September 2010). Regulations  

Safety

Freedom from unacceptable risk NOTE Adapted from lSO/lEC Guide 2:1996, definition 2.5. Source: ISO/IEC Guide 51:1999, Safety aspects – Guidelines for their inclusion in standards, Global Standards  

Safety

“Safety” means protection from danger arising out of, linked with or occurring in the course of employment. Source:  Nova Scotia Offshore Petroleum Occupational Health & Safety Requirements, Canada-Nova Scotia Offshore Petroleum Board, Canada, December 2000. Regulations  

Safety

Safety: the safety of persons and the protection of goods, in so far as no rules have been prescribed in this area by or by virtue of the Arbeidsomstandighedenwet 1988. Source: Mining Decree of the Netherlands, Netherlands, 2003 (as amended in 2007).  Legislation  

Safety

Freedom from unacceptable risk [2]. Source: ANSI/ISA–99.00.01–2007, Security for Industrial Automation and Control Systems, Part 1: Terminology, Concepts, and Models, 29 October 2007. National Standard
Foam

Foam

Definition(s)

Foam (Phase System)

Two-phase system, similar to an emulsion, in which the dispersed phase is air or gas. Source: API RP 13C, Recommended Practice on Drilling Fluids Processing Systems Evaluation, Upstream Segment, Fourth Edition, December 2010. Global Standards  

Foam (Floating Material)

Bubbles floating on the surface of the drilling fluid. NOTE The bubbles are usually air-cut drilling fluid but can be formation gasses. Source: API RP 13C, Recommended Practice on Drilling Fluids Processing Systems Evaluation, Upstream Segment, Fourth Edition, December 2010. Global Standards  

Foam

Foam is generally defined as gas dispersed in liquid in a ratio such that its bulk density approaches that of gas rather than liquid. Pure liquids rarely foam when gassed. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  

Foam

A two-phase system where the dispersed portion is air. Applied to UBD in water sensitive formations. Recyclable foams are available. Source: IADC UBO / MPD Glossary, December 2011. Global Standards  

Foam

Foam is the extinguishing medium produced when foam solution passes through a foam generator and is mixed with air. <fixed foam fire-extinguishing systems>. Source: IMO Resolution MSC.327(90), amendments to the International Code for Fire Safety Systems, 25 May 2012, International Maritime Organization. Regulatory Guidance  

Foam

Foam is the extinguishing medium produced when foam solution passes through a foam generator and is mixed with air. Source: IMO MSC.1/Circ.1271, Guidelines for the approval of high-expansion foam using inside air for the protection of machinery spaces and cargo pump-rooms, 4 June 2008, International Maritime Organization. Regulatory Guidance
Asphaltenes

Asphaltenes

Definition(s)

Asphaltenes

Asphaltenes are organic solids which appear similar to paraffin waxes and in the field can be difficult to distinguish visually from waxes. However, they are very different in chemistry and should be treated using approaches different from those used for waxes. While there is still much debate as to the exact nature of asphaltenes, one common definition is that asphaltenes are the fraction of the crude which is insoluble in light normal alkanes but soluble in aromatic solvents. Their actual make-up depends on the conditions at which they precipitate out of solution. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards
Wax

Wax

Definition(s)

Wax

Wax is typically defined as the high molecular weight paraffins which become insoluble in crude due either to the loss of light ends and/or a decrease in the temperature of the crude. Wax consists of straight-chain, branched or cyclic paraffins with carbon numbers typically ranging between C15 and C70+. The melting point of the wax increases with increasing carbon number, while the solubility in crude oil decreases with increasing carbon number. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  
Secondary Marking

Secondary Marking

Definition(s)

Secondary marking

Secondary marking is defined as the marking used within a major system or location to identify components such as valves, hydraulically operated components, local tapping points used for sensing equipment, probes, etc. A character height of 50 mm (1,969 in) to 150 mm (5,906 in) should be used. Smaller sizes may be used when the specified size is impractical. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  
Primary Marking

Primary Marking

Definition(s)

Primary marking

Primary marking is defined as marking of major structural members and systems that need to be identified for operational, installation, and retrieval purpose. Source: API Recommended Practice 17H, Remotely Operated Tools and Interfaces on Subsea Production Systems, Second Edition, June 2013 (Addendum 1, October 2014). Global Standards

Primary marking

Primary marking is defined as the marking of major structural members and systems that need to be identified for operational, installation and retrieval purposes. Recommended character height for marking of symbols is 170 mm (6,693 in) to 500 mm (19,685 in). Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  
Wet

Wet

Definition(s)

Wet

A gas system is defined as wet if part of the system operates below the water dew point. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  
TFL

TFL

Definition(s)

TFL

Through-flowline system. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards  

TFL

Through flowline. API RP 500, Recommended Practice for Classification of Locations for Electrical Installations at Petroleum Facilities Classified as Class I, Division 1 and Division 2, Third Edition, December 2012, Global Standards Source: API RP 17B, Recommended Practice for Flexible Pipe, Fourth Edition, July 2008. Global Standards Source: API SPEC 14A, Specification for Subsurface Safety Valve Equipment, Eleventh Edition, October 2005 (Reaffirmed June 2012). Global Standards  

TFL

Through-flowline (see ISO 13628-3). Source: API SPEC 17D, Design and Operation of Subsea Production Systems—Subsea Wellhead and Tree Equipment, Upstream Segment, Second Edition May 2011 (Errata September 2011). Global Standards  

TFL

Through-flowline Source: API SPEC 17J, Specification for Unbonded Flexible Pipe, Third Edition, July 2008. Global Standards
FAT

FAT

Definition(s)

FAT

Factory acceptance test. Source:  DNVGL-RP-G108, Cyber security in the oil and gas industry based on IEC 62443, DNV GL, September 2017. Global Standards Source: API Specification 16A, Specification for Drill-through Equipment, Fourth Edition, April 2017. Global Standards Source: API STANDARD 16AR, Standard for Repair and Remanufacture of Drill-through Equipment, First Edition, April 2017. Global Standards Source:API SPECIFICATION 19TT, Specification for Downhole Well Test Tools and Related Equipment, First Edition, October 2016. Global Standards Source: API Standard 2RD, Dynamic Risers for Floating Production Systems, Second Edition, September 2013. Global Standards Source: API Recommended Practice 17H, Remotely Operated Tools and Interfaces on Subsea Production Systems, Second Edition, June 2013 (Addendum 1, October 2014). Global Standards Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards Source: API RP 17B, Recommended Practice for Flexible Pipe, Fourth Edition, July 2008. Global Standards Source: API RP 17G, Recommended Practice for Completion/Workover Risers, Second Edition, July 2006 (Reaffirmed April 2011). Global Standards Source: API RP 17H, Remotely Operated Vehicle (ROV) Interfaces on Subsea Production Systems, First Edition, July 2004 (Reaffirmed January 2009). Global Standards Source: API SPEC 17D, Design and Operation of Subsea Production Systems—Subsea Wellhead and Tree Equipment, Upstream Segment, Second Edition May 2011 (Errata September 2011). Global Standards Source: API SPEC 17E, Specification for Subsea Umbilicals, Upstream Segment, Fourth Edition, October 2010. Global Standards Source: API SPEC 17F, Specification for Subsea Production Control Systems, Second Edition, December 2006 (Reaffirmed April 2011). Global Standards Source: API SPEC 17J, Specification for Unbonded Flexible Pipe, Third Edition, July 2008. Global Standards Source: NORSOK D-001, Drilling facilities, Rev. 3, December 2012. Global Standards Source: Verification of Lifting Appliances for the Oil and Gas Industry, DNV-OSS-308, October 2010, Det Norske Veritas AS, Global Standards  

FAT

Test conducted by the manufacturer to verify that the manufacture of a specific assembly meets all intended functional and operational requirements. Source: API Standard 2RD, Dynamic Risers for Floating Production Systems, Second Edition, September 2013. Global Standards  

FAT

Factory acceptance testing. Source: API TR 1PER15K-1, Protocol for Verification and Validation of High-pressure High-temperature Equipment, First Edition, March 2013. Global Standards
DNV

DNV

Definition(s)

DNV

Det Norske Veritas. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards Source: Offshore Standard DNV-OS-C101, Design of Offshore Steel Structures, General (LRFD Method, Det Norske Veritas, April 2011. Global Standards Source: Rules for Classification and Construction, IV Industrial Services, 6 Offshore Technology, 9 Guideline for Personnel Transfers by Means of Lifting Appliances, Edition 2011, Germanischer Lloyd SE, Global Standards Source: Verification of Lifting Appliances for the Oil and Gas Industry, DNV-OSS-308, October 2010, Det Norske Veritas AS, Global Standards
AC

AC

Definition(s)

AC

Alternating current. Source: API RP 17A, Design and Operation of Subsea Production Systems—General Requirements and Recommendations, Fourth Edition, Reaffirmed 2011. Global Standards Source: API SPEC 17F, Specification for Subsea Production Control Systems, Second Edition, December 2006 (Reaffirmed April 2011). Global Standards Source: API SPEC 17E, Specification for Subsea Umbilicals, Upstream Segment, Fourth Edition, October 2010. Global Standards Source: API RP 7G-2, Recommended Practice for Inspection and Classification of Used Drill Stem Elements, First Edition, August 2009. Global Standards Source: API RP 67, Recommended Practice for Oilfield Explosives Safety, Upstream Segment, Second Edition, May 2007. Global Standards