well_control_equipment
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Well Control Equipment
n Surface & Subsea BOP Equipment
– BOP annular and rams.
– Choke Manifold / Chokes.
– Accumulator unit and hydraulic lines.
n Mud Gas Separator.
n Drill string valves.
n Diverter.
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Well Control Equipment
At the end of this section you should be able to:
n Identify surface and subsea blowout preventors and
equipment.n Identify additional well control equipment at the rig site, and
describe their functions.
n Identify drill string valves and describe their functions.
n Identify the diverter equipment.
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Well Control EquipmentWell Control Equipment
If primary well control is lost*, the BOPs are closed and the well control equipment andtechniques are used to control the well.
The proper selection and utilization of the blowout preventers, chokes, choke manifolds,mud-gas separators, degassers, mud-monitoring equipment and all other well controlrelated equipment is an important aspect of well control. Among the main factorsaffecting the selection of well control equipment, there are:
n Pressure: working pressure rating must exceed the maximum anticipated surfacepressure.
n Temperature: rating of all elastomers (BOP rams, annular preventer bags, bonnets,valves, marine riser, kill/choke line connections, etc).
n Nature of well fluids: such as the presence of H2S.
n Fluid compatibility: the resistance of elastomers to OBM and completion fluid.
*Primary well control is achieved by controlling formation pressures with the hydrostatic pressure of the drillingfluid.
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Surface BOP StackSurface BOP Stack
The BOP stack is located over the wellhead and under drill floor in surfaceBOP’s.
They might include:
n Pipe ram preventer.n Drilling spool.
n Blind/shear ram preventer.
n Casing head housing.
The BOP’s is assembled inmany arrangements depending
upon requirements.Choke line
HCR
TOP RAM S
BLIND RAM S
BOTTOMRAMS
ANNULAR
BOTTOM RAM S
Kill line
VR plug m aybe installed in
casing head
Choke lineHCR
TOP RAM S
BLIND RAM S
BOTTOMRAMS
ANNULAR
BOTTOM RAM S
Kill line
VR plug m aybe installed in
casing head
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Subsea BOP StackSubsea BOP Stack
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BOP StackBOP Stack
The BOP stack consists of severalvalves, called preventers, stackedon top of each other. There are twokinds of preventers: annular preventer and ram preventers.
n Annular Preventer. – Close/seal on any object in the
wellbore.
– Sizes from 7-1/16 to 29-1/2 in.
– Pressures from 2K to 20K psi – Often called “the Hydrill”
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BOP StackBOP Stack
Ram Preventers:
n Pipe Rams:
– Fit a specific pipe size. – Need pipe to make a seal. – Reliable and field proven.
– Only hold pressure from bottom.
n Shear/Blind Rams: – Both shears drill pipe and seals
the hole.
– Capacity to cut through 5” drill
pipe. – Emergency equipment. – Top seal and side packers. – Can seal on open hole.
Top seal
Side Packers
Large frontal area
Top seal
Side Packers
Large frontal area
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Choke ManifoldChoke Manifold
The choke manifold is made up of specialhigh-pressure piping and valves. Thechoke manifold and chokes are used tocirculate formation fluids out of the well ina controlled manner. Fluid returning fromthe well flows from the BOP stack to thechoke manifold through a choke line.
Functions:
n Restrict flow to maintain backpressure, to prevent further influx.
n Divert fluid from well.
The choke can be opened and closed fromthe rig floor using the choke control panel.
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AccumulatorAccumulator
The accumulator unit pressurizes hydraulic fluid and stores it at highpressure to provide hydraulic energy to operate the BOPs.
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Mud Gas SeparatorMud Gas Separator
The mud-gas separator is a low-pressure vessel that removes gas from returningdrilling fluid. Proper design and efficiency of the mud-gas separator is very importantto ensure that drilling fluid is not carrying flammable gas to confined areas or mudtanks where rig personnel are working.
From c hoke
I m p i n g e m e n t
p l a t e
Baffle plates
1. Diameter and length controls theamount of pressure in separator
2. Height and diameter and internaldesign control separation efficiency
Drain linew/valve
Vent line
No valves!!
M UD
G A S
3. Height of ‘U’-Tube (D) and distancefrom bottom of separato r to top of ‘U’-Tube (d) contr ols fluid level and stopsgas from going out of the bottom
S i p h o n b r e a k e r
D
d N o v a l v e s ! !
M ud
From c hoke
I m p i n g e m e n t
p l a t e
Baffle plates
1. Diameter and length controls theamount of pressure in separator
2. Height and diameter and internaldesign control separation efficiency
Drain linew/valve
Vent line
No valves!!
M UD
G A S
3. Height of ‘U’-Tube (D) and distancefrom bottom of separato r to top of ‘U’-Tube (d) contr ols fluid level and stopsgas from going out of the bottom
S i p h o n b r e a k e r
D
d N o v a l v e s ! !
M ud
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Drill String ValvesDrill String Valves
Used to prevent the formation fluids going up the drill string. Different types of drillstring valves are:
n Full Opening Safety Valve: installed on top of the drill string when a kick is taken whilsttripping.
n Inside BOP: one-way valves that allow flow from drill string to annulus but not from annulusto drill string. An example is the float valve (flapper or ball valves), installed just above thebit.
Full openingsafety valve
Float valves
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DiverterDiverterThe diverter system is not an element of the well control equipment, it is notintended to shut-in or halt well flow. The diverter system, provides a low-pressure flowcontrol system to direct controlled or uncontrolled wellbore fluids away from theimmediate drilling area for the safety of personnel and equipment, while drillingsurface hole (prior to setting the surface casing on which the BOP stack and chokemanifold will be installed).
Surface
Casing shoe
Conductor
Diverter
Inf lux
Fl ow l in e
Dr i l ling str ing
Dive r te r l i ne
Ful l opening va lve ( in ter locked)
Sur face ho le
RiserSurface
Casing shoe
Conductor
Diverter
Inf lux
Fl ow l in e
Dr i l ling str ing
Dive r te r l i ne
Ful l opening va lve ( in ter locked)
Sur face ho le
Riser