PETE 625 Well Control

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PETE 625Well Control

• Lesson 18
• Well Control Equipment

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Well Control Equipment

• High Pressure Equipment
• Casing Design
• Control System Equipment and Design
• BOPE Inspection and Testing
• Low-Pressure Equipment
• Equipment Arrangement - Design and
  Philosophy

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Assignments

• HW 11 Ch 6, Problems 1, 3, 5,
  11 and 19 
•            Due Friday, July 16
• Read Chapters 6 7

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Schedule

• Project Abstracts are due on Friday, July
  16. Type-written, less than one page. 
  Drilling topic.
• QUIZ B Monday, July 12, 9-11 a.m. in
  Room 407M.
• Project Presentations Monday, July 19
• FINAL Wednesday, July 21, 9-11 a.m. in
  Room 511

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High Pressure Equipment

• Casing
• Casing Heads and Spools
• Stack Equipment
• Choke and Kill Line Equipment
• Drillstem Control Equipment

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( gt FG 0.91 psi/ft )
( at the surface )
1
( at the shoe )
... (7.2)
... (7.3)
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7,676
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9,211
7,676
5,368
4,473
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Drillpipe rotation can cause severe erosion on
the inside of the casing. Clearly, this can
result in a loss of casing pressure integrity.
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Casing Heads and Spools

• After surface casing is set, the casing is cut
• And wellhead is installed
• BOPE is N/U on the wellhead

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Fig. 7.3 Casing Heads and Spools
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Stack 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.

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Stack 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

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Annular Preventers
From Guide to Blowout Prevention by WCS, the
Well Control School
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Ram Preventer

• Also, see Multimedia Lesson 2

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Example 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

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Choke and Kill Line Equipment
Manual Choke
Remote Hydraulic Choke

• Also, see Multimedia Lesson 2

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Drillstem Control Equipment
Backpressure Valves
Dart Type Valve

• Also, see Multimedia Lesson 2

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Control System Equipment and Design

• Accumulator Design Principles
• Other Components
• Test Procedures

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Accumulator 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

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3,000 psig maximum
1,000 psig
1,150 psig
2,000 psig ?
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One annular preventer three ram preventers
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149.4 gal
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Low-Pressure Equipment

• Manifold Lines
• Mud-Gas Separators
• Degassers

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Mud-Gas Separators

• Primary means of separating gas from mud while
  controlling a kick, drilling underbalanced, or
  circulating large connection/trip gas.

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Fig. 7.19 Example Mud-Gas Separator
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Excessive 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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150-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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(time to vent gas)
Peak Rate in Vent Line
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This equation is based on giving the mud enough
retention time for the gas to migrate upwards
into the upper part of the chamber.
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Degassers

• Remove gas from the mud just downstream of the
  shale shaker

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Vacuum Degasser
Gas Cut Mud
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Equipment Arrangement Design and Philosophy

• Diverters
• Stack Arrangement
• Kill Line Considerations
• Choke Line and Manifold Design

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Diverters

• 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

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Diverter System
Diverter Lines should be sized as large as
practical for two reasons. 1. To keep two phase
friction down, and, 2. Prevent plugging
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Diverters

• 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.

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Stack Configuration A
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Stack Configuration A
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Stack Configuration B
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Stack Configuration B
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Stack Configuration C
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Stack Configuration C
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Stack Configuration D
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Stack Configuration D
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Choke Line and Manifold Design
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Choke Line and Manifold Design
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Fig. 7.28Example High-Pressure Choke Manifold