3 2 well control eq

Trang 1

Network of Excellence in Training

Well Control

Equipment

Trang 2

Basic Set Up

BOPs are rated

by API as;

3M (3000 psi), 5M,

10M and 15M,

for HPHT wells;

15M or 20M,

Blow-out Preventers

Trang 3

Annular

Trang 5

Annular

Open Close

Trang 6

Pipe rams are designed to close and seal on one specific size

of pipe, and are also used for "hang-off

Pipe rams

Trang 7

With hang-off, the ram is used to suspend pipe

or casing by closing underneath a tool joint

The recommended procedure for emergency hangoff of drill pipe is to close the rams with 1,500 psi up to 3,000 psi, lock the ram locks using the normal procedure, and then

transfer the drill pipe weight to the rams.

Pipe rams

Trang 8

Pipe rams‘ hang off suspension capacity

varies with the size of the ram.

Pipe rams

Trang 9

Rams

Trang 10

Rams

Trang 12

Shearing Blind Rams Shearing blind rams (SBRs) are dual-purpose rams that have been proven over many years of field service.

Under normal operating conditions, they are used as blind rams to seal in an open hole When used as a blind ram, the blade packer in the upper shear ram seals against the front face of the lower shear ram In an emergency, SBRs are used for shearing

Rams

Trang 13

Shearing Blind Rams

Rams

Trang 14

Dual String (DS) Shearing Blind Ram The dual string shearing blind ram, also known as the DS Shear Ram

was originally designed to shear larger diameter tubulars or multiple tubing strings, regardless of their orientation to the centerline of the ram bore.

With the DS Shear Ram, after the pipe has been sheared, the lower

pipe (or "fish") is housed in a vertical pocket The blade face seal provides a seal between the horizontal faces of the upper and lower blades.

Rams

Trang 15

Dual Shear Rams

Rams

Trang 16

Variable Bore Rams

1 The Variable Bore Ram, or VBR, seals on several sizes of pipe

or hexagonal kelly within its specified size range A typical range is from 5" to 3-1/2" diameter Other size ranges, such as 7" to 4-1/2" diameter, are available upon request.

2 VBRs are not intended for long-term stripping use

3 "Stripping" refers to moving drill pipe vertically within the

well while the BOPs remain closed, maintaining a seal around the pipe

4 During stripping, the drill pipe and larger diameter tool joints

are pulled through the packers in fully closed rams This procedure is typically used in workover and servicing operations using annular BOPs and specialty rams.

Rams

Trang 17

Variable Rams

Rams

Trang 18

Variable Rams

Trang 19

HCR Valve

Trang 20

HCR Valve

The HCR pressure operated gate valve is a flowline valve requiring relatively low operating pressure It is a single ram, hydraulic gate valve The closing ratio of well pressure to hydraulic operating pressure is

approximately 8:1.

Should the the HCR valve be used as the inner

or outer kill valve on the

the BOP stack?

Trang 21

1 The purpose of the unit is to operate and control equipment to

safely control kicks and prevent blowouts during drilling and workover operation

2 The prime function of this unit is to provide and store the

fluid supply for the pumps and the high-pressure operating system that operates and controls the BOP stack

3 A Blow-Out Preventer (BOP) control system is a

high-pressure hydraulic power unit fitted with directional control valves

4 Accumulator or Accumulator unit consist of electric pumps,

air pumps, hydraulic control panel, air operated control panel, valves, accumulator bottles and reservoir tank

Accumulator Unit

Trang 22

Trang 23

Pipings & Gauges

Trang 24

Bank of Accumulators

Trang 25

Usable Volume = Vb-Va

Trang 26

1 Accumulators or bottles as they are more commonly

know come in different size and pressure rating

2 They are coded to ASME specifications

3 These bottles store the pressure that function the well

control equipment

4 There are two basic types Bladders and Floats

5 they come as Cylinders or Ball style and can be either top

or bottom loaded

6 Inside are the rubber bladders used to store pressured

nitrogen The nitrogen is stored at 1000 psi

Accumulators

Trang 27

The tank normally oblong stores the atmospheric fluid supply for

the high-pressure pumps

It contains baffle plates Inspection ports, fill up and drain off lines The fluid stored could be either hydraulic oil or soluble oil that

mixes with water.

Once the accumulator bottle's are pressured up, the tank will hold

the reserve fluid that should be checked daily.

It is a good idea to install a low level indicator to the tank

Reservoir

Trang 28

• 1 or 2 hydraulic air pumps make up an independent

pressure assembly unit

• All are run in parallel and are connected to the

accumulator piping system to provide a source of high pressure

• All pumps no matter whether they be air or electrical

must be rated so as to fully charge the Pressure system from 0 to 3000 psi in 15 min This is to be done as an independent unit.

Air Pumps

Trang 29

• Electrical pumps are used to pump high-pressure

fluid They can be duplex or triplex receipting plunger type pumps (piston) driven by explosion proof electric motors

• Each pump source for a 3000 psi high pressure

system should be able to open the HCR valve, close the annular prevented and close the choke within 2 minutes with the accumulator bottle isolated and

1200 psi on the manifold.

Electric Pumps

Trang 30

• The manifold is the control centre that contains all the leaver

and valves that operate and control the direction the pressure fluid will go

high-• The accumulated pressure is regulated down to a working

pressure of 1500 psi for valve and rams and 800 psi for the annular presenter

• There are 3 pressure gauges installed to show the

pressure 3000, 1500 and 800 psi and should be checked daily

• The leavers have nameplates to indicate their function

Would normally have some form of safety plate or cover to stop people accidentally closing it (the blind or shear rams)

Hydraulic Control Manifold

Trang 31

• This is commonly known as the remote control unit

• stationed a safe ( minimum 50 feet away ) and covenient

distance from the rig

• As the name implies it is, operated by air.

• More modem rigs have a push button system installed in

the Toolpushers Office

• However, on land this is somewhat rear

• This control system is a two handed operation : a to

controls air, b.the other to activate the equipment An airline connects it to the accumulator unit. Air remote control interface

Air remote control panels

Trang 32

For the remote to work there has to be a air remote control panel that interfaces both the remote and the

accumulator. This is made up of stainless steel 1/4 tubing

Other components include air cylinders, regulators pressure transmitters and half of the air transmission box such a

system is quite complicated and could link to 1 or more remote controls.

Air remote control interface assembly

Trang 33

• The accumulator unit and remotes are connected up

with flame resistant muli conductor air cable (Umbilical Cable)

• This cable has an outer casing with 3/8-polyethylene

line inside that carries the air signal At each end is the other half of the air transmission box.

• That once coupled up complete the operating circuit

Interconnecting cables assembly

Trang 34

• The correct approach to sizing an accumulator unit should

incorporate ample accumulator capacity to immediately control the Preventers in an emergency

• The pumps must be designed too charge the system within a

reasonable time and maintain this charge

• The total accumulator volume for a 3000-psi standard

control system should be sized to close the annular and all the BOP rams and valve with the pumps out of service

While holding a minimum of 1200 psi operating pressure -200 psi above pre charge

• An additional 50% of fluid should be applied to compensate

for any fluid loss in the control system or Preventer

Sizing recommendation for a standard system

Trang 35

Trang 36

Choke Manifold

Trang 37

Choke Manifold

Trang 38

• When a well kicks , it is closed

in

• After evaluation the well will be

killed

• This process can take several

forms most involving the use of a choke, some form of throttle

Choke Manifold

Trang 39

• Features: a dual chokes, one adjustable and one positive, to help

maintain a constant flow rate, which controls the pressure at the bottom of the hole "Bottom Hole Pressure"

• Another feature is a straight through by pass enabling the flow to go

directly to the sump a safety feature no manifold should be without

• Chokes are throttling valves that allow operators to control the well

stream They are capable of withstanding erosion resulting from the very high velocities occurring at and immediately downstream from the orifice Choke Manifold allows operators to limit erosion to the replaceable parts within the choke

• Direct flows to different areas of the rig Redirect flow shouldr some

unforeseen reason repair need to be made during the kill

Choke Manifold

Trang 40

• There is no standard drilling choke

• Ideally the choke should be as close to the drilling

console as possible

• Should this not be possible a remote control and a

automatic choke should be part of the standard equipment list

• The basic standard drilling choke manifold should be

designed with a full-bore flow path through the manifold, allowing total bypass of the choke control

• On one side of the bypass, an adjustable choke allows

more flexible control for well, on the other side is a positive choke to give more accurate flow

• By using the valves and choke, the operator can change

the choke without having to stop the operation

Choke Manifold

Trang 41

Choke Manifold

Trang 42

• Pressure gauges from both the stand pipe manifold

and the choke should be connected to the remote and

be independent line

• Both a low and high pressure gauge should be used

an the choke

• Part of the training drills should include the lining up

of the choke circulating system

• this is more apparent on land where the choke can be

up to 50 feet from the rig and the driller may have to walk away from the control panel to see what is going

on

Pressure Gauges

Trang 43

J-2 step-down pressure transmitters, normally located on the standpipe and the choke

manifold, convert actual mud pressure to a low pressure pneumatic signal.

These signals are transmitted through hoses to the control console where pressure readings are registered on the panel gauges

J-2 is a hydraulic transmitter working at 300 psi

Pressure Gauges

Trang 44

Cameron hydraulically actuated drilling chokes are available in working pressure rated from 5000 to 20,000 psi with inlet and outlet flange sizes from 3-1/16" to 4-1/16"

The standard orifice size is 3/4" Other sizes are available All parts rated suitable for H2S and 250øF service The cylindrical gate and large body cavity provide high flow

1-capacity and quiet operation

The gate and seat can be replaced or reversed without removing the choke from the

Hydraulically Actuated Drilling Choke

Trang 45

Manual Drilling Choke

Trang 46

Degasser

Trang 47

Drilling Spools: used as an element between rams to provide mud exist lines such as choke and kill lines Drilling spool can be flanged, studded or clamp-on type.

• For air drilling, rotating heads are used to allow well control

while the pipe is rotating.

• Drillpipe Blowout Preventers include:

– Kelly cock,– Drop in valve (check valve),– Float valve (either flapper or spring-loaded ball valve),

– Full opening safety valves

• All above equipment must be rated to the highest pressure to be

expected at the well during a kick or during controlled testing and production

Other BOP Equipment

Trang 48

– In subsea operations, the BOP stack is installed at

seabed,

– The stack has several back-up units in the case of

failure, for example two annulars are used so that if one failed the other can be used,

– This back-up system principle is applied to all the BOP

components,

of the rig contract and may have to be rented out separately, e.g a 20 K stack

Subsea BOP Equipment

Trang 49

Drop in Valve

Checkguard valve is

installed as needed

Safety Valves

Trang 50

The check valve sits in the landing sub in the replaceable landing sleeve, latching positively The sleeve has recessed areas into which the check valve packer seals.

Checkguard valve seals pressure up to 10,000 psi

Drop in Valve

Safety Valves

Trang 51

It is wire line retrievable

The need to trip the drill string is eliminated

Yet retrieval can also be accomplished after tripping out the drill string In this illustration, the retrieving tool unlatches the check valve and lifts it to the surface

Landing Sub After the correct size check valve is determined, choose a matching landing sub

Select a landing sub with threaded connections and outside diameter compatible with the mating tool joints of the drill string.

Drop in Valve

Safety Valves

Trang 52

• Most valve of this nature are some form of ball valve

that can be operated both manually or in some cases hydraulically as if installed in a top drive

• Kelly Valves are manually operated high-pressure

safety valves

• They provide positive sealing for upward and

downward pressures and are used for multiple applications.

• Kelly Valves are installed e g in drill stems or tubing

strings Often used as an inside BOP and would be installed in the open position

• The Valve will than be closed to shut in any flow If the

flow starts while the rig is tripping a Gray inside BOP would be installed above it The Kelly Valve would then

Kelly Valve

Safety Valves

Trang 53

Kelly Valve

Safety Valves

Trang 54

Identify the valves to be lined up for

a leak off test through the drillstring with the cement pump.

Circle either open (O) or closed (O) for each valve below:

Valve No.1 : Valve No.2 : Valve No.3 : Valve No.4:

Valve No.5 :

Trang 55

Network of Excellence in Training

Well Control

Equipment

End Of Lecture

Định dạng
Số trang	55
Dung lượng	9,92 MB