Oil & Gas Drilling Glossary - IADCLexicon.org
A methodology whereby flaws and other deterioration/damage or operating conditions contained within a pressure vessel are assessed in order to determine the integrity of the vessel for continued service.
Source: API 510, Pressure Vessel Inspection Code: In-service Inspection, Rating, Repair, and Alteration, Tenth Edition, May 2014, with Addendum May 2017. Global StandardsSource: API 510, Pressure Vessel Inspection Code: In-service Inspection, Rating, Repair, and Alteration, Tenth Edition, May 2014, with Addendum May 2017. Global Standards
Any type of deterioration encountered in the refining and chemical process industry that can result in flaws/defects that can affect the integrity of vessels (e.g. corrosion, cracking, erosion, dents, and other mechanical, physical, or chemical impacts). See API 571 for a comprehensive list and description of damage mechanisms.
Source: API 510, Pressure Vessel Inspection Code: In-service Inspection, Rating, Repair, and Alteration, Tenth Edition, May 2014, with Addendum May 2017. Global StandardsAny type of deterioration encountered in the refining and chemical process industry that can result in metal loss/flaws/ defects that can affect the integrity of piping systems (e.g. corrosion; cracking; erosion; dents; and other mechanical, physical, or chemical impacts). See API 571 for a comprehensive list and description of damage mechanisms that may affect process piping systems in the refining, petrochemical and chemical process industries.
Source: API 570, Piping Inspection Code: In-service Inspection, Rating, Repair, and Alteration of Piping Systems, Fourth Edition, February 2016, with Addendum May 2017. Global StandardsRefers to service conditions that may produce fatigue damage due to cyclic loading from pressure, thermal, and mechanical loads that are not induced by pressure. Other cyclic loads associated with vibration may arise from such sources as impact, turbulent flow vortices, resonance in compressors, and wind, or any combination thereof. See 5.4.4. Some examples of vessels in cyclic service include coke drums, mole sieves, and pressure swing adsorbers.
Source: API 510, Pressure Vessel Inspection Code: In-service Inspection, Rating, Repair, and Alteration, Tenth Edition, May 2014, with Addendum May 2017. Global StandardsRefers to service conditions that may result in cyclic loading and produce fatigue damage or failure (e.g. cyclic loading from pressure, thermal, and/or mechanical loads). Other cyclic loads associated with vibration may arise from such sources as impact, turbulent flow vortices, resonance in compressors, and wind, or any combination thereof. Also see API/ASME 579-1/ASME FFS-1, Definition of Cyclic Service, in Section I.13 and screening methods in Annex B1.5, as well as the definition of “severe cyclic conditions” in ASME B31.3 Section 300.2, Definitions.
Source: API 570, Piping Inspection Code: In-service Inspection, Rating, Repair, and Alteration of Piping Systems, Fourth Edition, February 2016, with Addendum May 2017. Global StandardsRefers to all forms of CUI including stress corrosion cracking and corrosion under fireproofing.
Source: API 510, Pressure Vessel Inspection Code: In-service Inspection, Rating, Repair, and Alteration, Tenth Edition, May 2014, with Addendum May 2017. Global StandardsExternal corrosion of carbon steel and low alloy steel piping resulting from water trapped under insulation. External chloride stress corrosion cracking (ECSCC) of austenitic and duplex stainless steel under insulation is also classified as CUI damage.
Source: API 570, Piping Inspection Code: In-service Inspection, Rating, Repair, and Alteration of Piping Systems, Fourth Edition, February 2016, with Addendum May 2017. Global StandardsCentral portion of the head is defined as the center of the head with a diameter equal to 80 % of the shell diameter.
Source: API 510, Pressure Vessel Inspection Code: In-service Inspection, Rating, Repair, and Alteration, Tenth Edition, May 2014, with Addendum May 2017. Global StandardsPart of a specially-designed section of piping installed on a drilling rig for use during well control incidents and not for MPD. This manifold and any associated choke(s) are designed for lower flow rates and higher pressures than those used for drilling.
Source: ABS Guide for Classification and Certification of Managed Pressure Drilling Systems, September 2017. Global StandardsDescriptive term used to apply to any item intentionally used in a wet condition below the sea water level. Subsea service requires multiple design features for that purpose, depending on each piece of equipment.
Source: ABS Guide for Classification and Certification of Managed Pressure Drilling Systems, September 2017. Global StandardsA form of MPD utilizing pumps located on the sea floor to pump the mud and cuttings returns back to the surface. This system may also employ a rotating seal above the BOPs and can create or reduce back-pressure on the wellbore by varying the pump operating speed and RCD configuration.
Source: ABS Guide for Classification and Certification of Managed Pressure Drilling Systems, September 2017. Global StandardsThe elastomeric sealing element installed inside the rotating control device to seal around the drill string.
Source: ABS Guide for Classification and Certification of Managed Pressure Drilling Systems, September 2017. Global StandardsMPD technique which diverts returned fluid flow away from the rig floor in order to handle any formation fluid influx, thereby avoiding closing of a BOP, with the subsequent well control steps that are customarily required. RFC is drilling with a closed annulus return system (RCD) immediately under the rig floor for complete assurance of the total diversion of any rapidly developing kick.
Source: ABS Guide for Classification and Certification of Managed Pressure Drilling Systems, September 2017. Global StandardsPhrase used to describe the first well barrier that prevents flow from a source.
Source: ABS Guide for Classification and Certification of Managed Pressure Drilling Systems, September 2017. Global StandardsA drilling process that involves maintaining a mud level in the annulus below the surface for hole stability and well control purposes, and no surface back-pressure. In MCD, there are no flow returns to the surface while maintaining mud column on the annular side. There exists several MCD variations, such as PMCD, FMCD etc. MCD is an umbrella term used for FMCD and PMCD.
Source: ABS Guide for Classification and Certification of Managed Pressure Drilling Systems, September 2017. Global StandardsA device installed in the drilling riser below the RCD to make possible removing and replacing a worn RCD sealing/bearing element while back-pressure is being applied. MPD annular may be used to isolate the RCD during emergencies such as a gas in riser event.
Source: ABS Guide for Classification and Certification of Managed Pressure Drilling Systems, September 2017. Global StandardsA drilling technique used to drill without returns while sacrificial fluid is continuously pumped down drill string and the annulus to avoid all possibility of formation fluid migrating to the surface. Open-hole formation is taking all injected (sacrificial) fluid and drilled cuttings without surface pressure assistance.
Source: ABS Guide for Classification and Certification of Managed Pressure Drilling Systems, September 2017. Global StandardsA variant of Dual Gradient Drilling (DGD) used only on floating rigs by placing a special pump in/on the drilling riser to vary the level of fluid in the drilling riser. The fluid level is adjusted up or down to control bottom-hole pressure and to compensate for variations in equivalent circulating density due to frictional pressure losses.
Source: ABS Guide for Classification and Certification of Managed Pressure Drilling Systems, September 2017. Global Standards