Title: TAMU Pemex Well Control
1TAMU - PemexWell Control
- Lesson 18
- Well Control Equipment
2Well Control Equipment
- High Pressure Equipment
- Casing Design
- Control System Equipment and Design
- BOPE Inspection and Testing
- Low-Pressure Equipment
- Equipment Arrangement - Design and
Philosophy
3High Pressure Equipment
- Casing
- Casing Heads and Spools
- Stack Equipment
- Choke and Kill Line Equipment
- Drillstem Control Equipment
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7( gt FG 0.91 psi/ft )
( at the surface )
1
( at the shoe )
... (7.2)
... (7.3)
87,676
99,211
7,676
5,368
4,473
10Drillpipe rotation can cause severe erosion on
the inside of the casing. Clearly, this can
result in a loss of casing pressure integrity.
11Casing Heads and Spools
- After surface casing is set, the casing is cut
- And wellhead is installed
- BOPE is N/U on the wellhead
12Fig. 7.3 Casing Heads and Spools
13Stack Equipment
- Basic functions
- Seal the well against the drillstring or open
hole and contain well pressure - Provide a a full-bore opening to allow passage
of drilling and testing tools - Permit unrestricted flow of fluids to the choke
line while the preventers are closed.
14Stack Equipment
- Basic functions
- Allow drillstring movement when the well is
shut-in to prevent sticking or allow stripping - Provide a way to allow fluids to be pumped into
the well below a closed preventer - Convey drilling fluid to the bell nipple and
flowline
15Annular Preventers
From Guide to Blowout Prevention by WCS, the
Well Control School
16Ram Preventer
- Also, see Multimedia Lesson 2
17Example 7.2
- Given
- Closing ratio for rams is 7.3
- SIP 9,000 psi
- Closing friction 200 psi
- Control-fluid friction loss 300 psi
- What is the minimum closing pressure?
- Eq. 7.6 yields
- pcl 1,733 psig
18Choke and Kill Line Equipment
Manual Choke
Remote Hydraulic Choke
- Also, see Multimedia Lesson 2
19Drillstem Control Equipment
Backpressure Valves
Dart Type Valve
- Also, see Multimedia Lesson 2
20Control System Equipment and Design
- Accumulator Design Principles
- Other Components
- Test Procedures
21Accumulator Design Principles
- Store hydraulic fluid under pressure to operate
the BOPE. - Most utilize a precharge pressure of 1,000 psig
and have a working pressure of 3,000 psig. - Precharge supplies the driving energy when the
bottle is fully depleted
223,000 psig maximum
1,000 psig
1,150 psig
2,000 psig ?
23One annular preventer three ram preventers
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25149.4 gal
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30Low-Pressure Equipment
- Manifold Lines
- Mud-Gas Separators
- Degassers
31Mud-Gas Separators
- Primary means of separating gas from mud while
controlling a kick, drilling underbalanced, or
circulating large connection/trip gas.
32Fig. 7.19 Example Mud-Gas Separator
33Excessive friction pressure in flare line
Eq 7.8, The Weymouth equation can be used to
predict gas friction pressure
can cause evacuation of the separator and gas
can blow through mud outlet
The allowable separator pressure is equal to pml
gmhml
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35150-ft vent line, three sharp bends
Circulation Rate 175 gal/min
Equivalent Length 360 ft
Vent line Diameter ? Separator Diameter ?
Mud Leg Height
7 ft
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37(time to vent gas)
Peak Rate in Vent Line
38This equation is based on giving the mud enough
retention time for the gas to migrate upwards
into the upper part of the chamber.
39Degassers
- Remove gas from the mud just downstream of the
shale shaker
40Vacuum Degasser
Gas Cut Mud
41Equipment Arrangement Design and Philosophy
- Diverters
- Stack Arrangement
- Kill Line Considerations
- Choke Line and Manifold Design
42Diverters
- Diverters are used when the decision has been
made to NOT shut-in the well on a kick - Usually done prior to setting surface casing
- Fear is that shutting in the well would result
in formation fracture and broaching to the
surface
43Diverter System
Diverter Lines should be sized as large as
practical for two reasons. 1. To keep two phase
friction down, and, 2. Prevent plugging
44Diverters
- When a well is put on diverter, the well is out
of control, and the goal is to restore control
as quickly as possible. - This is done by pumping mud as fast as the
pumps can while increasing the mud weight.
45Stack Configuration A
46Stack Configuration A
47Stack Configuration B
48Stack Configuration B
49Stack Configuration C
50Stack Configuration C
51Stack Configuration D
52Stack Configuration D
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56Choke Line and Manifold Design
57Choke Line and Manifold Design
58Fig. 7.28Example High-Pressure Choke Manifold