ISO/TR 13624-2:2009 石油および天然ガス産業—掘削および生産設備—パート2：深海掘削ライザーの方法論、操作、および完全性テクニカルレポート | ページ 6

3.1

accumulator

pressure vessel charged with gas (e.g. nitrogen) over liquid and used to store hydraulic fluid under pressure for operation of blowout preventers

3.2

accumulator

riser tensioner

pressure vessel charged with gas (e.g. nitrogen) over liquid that is pressurized on the gas side from the tensioner high-pressure gas supply bottles and supplies high-pressure hydraulic fluid to energize the riser tensioner cylinder

3.3

air-can buoyancy

tension applied to the riser string by the net buoyancy of an air chamber created by a closed-top, open-bottom cylinder forming an air-filled annulus around the outside of the riser pipe

3.4

annulus

space between two pipes, when one pipe is positioned inside the other

3.5

apparent weight

effective weight

submerged weight

riser weight in air minus buoyancy

Note 1 to entry: Apparent weight is commonly referred to as weight in water, wet weight, submerged weight or effective weight.

3.6

auxiliary line

conduit (excluding choke-and-kill lines) attached to the outside of the riser main tube

3.7

ball joint

ball-and-socket assembly having a central through passage that has an internal diameter equal to or greater than that of the riser and that may be positioned in the riser string to reduce local bending stresses

3.8

blowout

uncontrolled flow of well fluids from the well bore

3.9

blowout preventer

BOP

device attached immediately above the casing, which can be closed to shut in the well

3.10

blowout preventer

remotely controlled device that can form a seal in the annular space around any object in the well bore or upon itself

Note 1 to entry: Compression of a reinforced elastomer packing element by hydraulic pressure affects the seal.

3.11

BOP stack

assemblage of well-control equipment, including BOPs, spools, valves, hydraulic connectors and nipples, that connects to the subsea wellhead

Note 1 to entry: Common usage of this term sometimes includes the lower marine riser package (LMRP).

3.12

box

female member of a riser coupling, C&K line stab assembly or auxiliary line stab assembly

3.13

buoyancy-control line

auxiliary line dedicated to controlling, charging or discharging air-can buoyancy chambers

3.14

buoyancy modules

devices added to riser joints to reduce their apparent weight, thereby reducing riser top tension requirements

3.15

choke-and-kill lines

kill line

C&K lines

external conduits arranged laterally along the riser pipe and used for circulation of fluids into and out of the well bore to control well pressure

3.16

control pod

assembly of subsea valves and regulators that, when activated from the surface, directs hydraulic fluid through special porting to operate BOP equipment

3.17

coupling

mechanical means of joining two sections of riser pipe in an end-to-end engagement

3.18

diverter

device attached to the wellhead or marine riser to close the vertical flow path and direct well flow away from the drill floor and rig

3.19

drift-off

unplanned lateral move of a dynamically positioned vessel off its intended location relative to the wellhead, generally caused by loss of either stationkeeping control or propulsion

3.20

drilling fluid

mud

water- or oil-based fluid circulated down the drillpipe into the well and back up to the rig for purposes including containment of formation pressure, the removal of cuttings, bit lubrication and cooling, treating the wall of the well and providing a transmission medium for well data

3.21

drive-off

unplanned move of a dynamically positioned vessel off location driven by the vessel's main propulsion or stationkeeping thrusters

3.22

dynamic positioning

computerized means of maintaining a vessel on location by selectively driving and/or directing thrusters

3.23

effective tension

axial tension that is calculated at any point along a riser in water considering only the top tension and the apparent weight of the riser and its contents

Note 1 to entry: See ISO 13624-1:2009, 5.4.3, and Sparks, 1984.

3.24

factory acceptance testing

FAT

testing by a manufacturer of a particular product to validate its conformance to performance specifications and ratings

3.25

fill valve

valve used to fill the riser with seawater to prevent riser collapse

3.26

fleet angle

angle between the vertical axis and a riser tensioner line at the point where the line connects to the telescopic joint

Note 1 to entry: This angle changes with change in elevation of the vessel.

3.27

flex joint

steel and elastomer assembly having a central through-passage area equal to or greater than the riser bore

Note 1 to entry: Flex joints are commonly placed at the bottom of the riser to reduce local bending stresses at the transition from riser to lower marine riser package.

3.28

heave

vessel motion in the vertical direction

3.29

hot-spot stress

local peak stress

highest stress in the region or component under consideration, which causes no significant distortion and is principally objectionable as a possible initiation site for a fatigue crack

Note 1 to entry: These stresses are highly localized and occur at geometric discontinuities.

3.30

hydraulic connector

a mechanical device that is activated hydraulically and connects the BOP stack to the wellhead or the LMRP to the BOP stack

3.31

hydraulic supply line

auxiliary line from the vessel to the subsea BOP stack that supplies control-system operating fluid to the LMRP and BOP stack

3.32

jumper hose

flexible section of choke, kill or auxiliary line that provides a continuous flow around a flex/ball joint while accommodating the angular motion at the flex/ball joint

3.33

lower marine riser package

LMRP

upper section of a two-section subsea BOP stack consisting of a hydraulic connector, annular BOP, ball/flex joint, riser adapter, jumper hoses for the choke, kill and auxiliary lines, and subsea control pods

Note 1 to entry: The LMRP lands in the top of the lower subsea BOP stack.

3.34

mud-boost line

auxiliary line that provides a supplementary fluid supply from the surface and injects it into the riser at the LMRP to assist in the circulation of drill cuttings up the marine riser, when required

3.35

pin

male member of a riser coupling or a choke, kill or auxiliary line stab assembly

3.36

pup joint

shorter-than-standard length riser joint

3.37

response amplitude operator

RAO

ratio of a vessel's motion to the wave amplitude causing that motion and presented over a range of wave periods

3.38

riser adapter

crossover between riser and flex/ball joint

3.39

riser disconnect

operation of unlatching of the riser connector to separate the riser and LMRP from the BOP stack

3.40

riser joint

section of the riser main tube having ends fitted with a box and pin and including choke, kill and (optional) auxiliary lines and their support brackets

3.41

riser main tube

riser pipe

seamless or electric welded pipe that forms the principal conduit of the riser joint that guides the drill string and contains the return fluid flow from the well

3.42

riser string

deployed assembly of riser joints

3.43

riser tensioner

means for providing and maintaining top tension on the deployed riser string to prevent buckling

3.44

riser tensioner ring

structural interface of the telescopic joint outer barrel and the riser tensioners

3.45

rotary kelly bushing

RKB

commonly used vertical reference from the drillfloor

3.46

slip joint

telescopic joint

riser joint having an inner barrel and an outer barrel with means of sealing in between

Note 1 to entry: The inner and outer barrels of the telescopic joint move relative to each other to compensate for the required change in the length of the riser string as the vessel experiences surge, sway and heave.

3.47

stab

mating box and pin assembly that provides pressure-tight engagement of two pipe joints

Note 1 to entry: An external mechanism is usually used to keep the box and pin engaged.

Note 2 to entry: Riser joint choke-and-kill stabs are retained in the stab mode by the make-up of the riser coupling.

3.48

standard riser joint

joint of typical length for a particular drilling vessel's riser storage racks, the derrick V-door size, riser handling equipment capacity or a particular riser purchase

3.49

strakes

helically wound appendages attached to the outside of the riser to suppress vortex-induced vibrations

3.50

stress amplification factor

SAF

ratio of the local peak alternating stress in a component (including welds) to the nominal alternating stress in the pipe wall at the location of the component

Note 1 to entry: This factor is used to account for the increase in the stresses caused by geometric stress amplifiers that occur in riser components.

3.51

surge

vessel motion along the fore/aft axis

3.52

sway

vessel motion along the port/starboard axis

3.53

terminal fitting

connection between a rigid choke, kill or auxiliary line on a telescopic joint and its drape hose, effecting a nominal 180° turn in flow direction

3.54

vortex-induced vibration

VIV

in-line and transverse oscillation of a riser in a current induced by the periodic shedding of vortices

3.55

wellhead connector

stack connector

hydraulically operated connector that joins the BOP stack to the subsea wellhead