completion equipments

2/19/2014

1

WELL COMPLETION EQUIPMENTS

Thanks to: Prof. Bahman Tohidi(Heriot-Watt University) Well design and completionwww.utp.edu.my

By: Dr. Syahrir Ridha

Having worked through this chapter the Student will be able to:

Discuss and review the main equipment options: Production tubing Wellheads Xmas trees Packers Subsurface safety valves Nipple profiles Tubing-annulus circulation devices

Lesson Outcomes

Well design and completionwww.utp.edu.my

2/19/2014

2

1. Production Tubing2. Wellhead Systems3. X-mas Tree4. Packers5. Nipple and Mandrel Systems6. Sub-Surface Safety Systems7. Tubing-Annulus Communication Equipment

Completion Equipments

1. Production Tubing

Design of production tubing should satisfy the following criteria:

Minimising pressure dropHigh strength for suspension of tubing jointsHigh internal pressures for fluids flowHigh external pressures (between annulus &

tubing)Resistant to chemical corrosion


2/19/2014

3

Production Tubing

Tubing Diameter‐ OD + lbs/ft (4” OD, 9.5 lbs/ft)

Tensile Strength‐ H-40, C-75, L-80, et al‐ Number is an indication of minimum

yield strength multiply 1000 in psi.‐ Letter grades indicate the

manufacturing process Internal Pressure

‐ Internal vs differential pressure‐ Burst pressure is calculated for gas

filled tubing‐ Maximum generally occurs at surface


Production Tubing

External Pressure‐ Collapse is most likely at the bottom of the well

Corrosion‐ Acid corrosion; i.e. CO2‐ Sulphide stress cracking/hydrogen embitterment;

i.e. H2S‐ Some treatment use of inhibitor

Coupling Types‐ Connections that require internal pressure‐ Metal to metal


2/19/2014

4

2. Wellhead Systems


Wellhead Systems

It has the following functions: Suspension of casings and tubings Flanging up fluid flow devicesX-mas tree and/or BOPs

Hydraulix communication with annulus

Application in an offshore platforms or land based, wellhead can be devided into: Conventional Spool System Compact Spool Systems Mud Line Suspension System


2/19/2014

5

a. Run the 30” conductor, 20” casing is run and cemented. Sometimes the top of 20” casing is welded, so it can transfer some weigh to the 30” conductor.

b. The 17 ½” hole is drilled,13 3/8” casing is run with the hanger landing in the 20” housing. The casing is cemented in place.

c. A new 12 ¼” hole is drilled…with a new spool being installed for each casing string.

Conventional Spool System


The disadvantages of this type of wellhead are:

A lot of time is spent flanging up the spools; The large number of seals, increases the

chance of pressure leak; BOPs must be removed to install the next

casing spool; A lot of headroom is require, which may not

be available in the wellhead area of an offshore platform.

Conventional Spool System


2/19/2014

6

Compact Spool System

This compact type was developed as an alternative to the conventional spool discussed above.

A compact spool enables several casing strings or tubing to be suspended from a single spool.

The BOPs can be connected to the top of housing and the next hole section drilled.


Compact Spool System


2/19/2014

7

Mud Line Suspension System

Wellhead is built up on the seabed, but production well be completed back to the platform.

A wellhead built up on the seabed will be used to suspend casing strings

Each casing will have an extension string from subsea wellhead to a subsidiary wellhead at the platform where the BOP and X-mas tree will be attached.


3. X-mas Tree

It is a system of valves which controls physical or hydraulic access into the tubing string or the annulus.

The access capabilities required are: Capability to inject fluids Capability to produce fluids Capability to lower wireline service tool Capability to completely close the well

‐ Manually controlled valve and remotely controlled valve (hydraulically)


2/19/2014

8


X-mas Tree

One major disadvantage of cross piece Xmas Tree is the large number of flanges significantly increased possibility of leakage.


X-mas Tree

A solid block construction uses of a yoke piece configuration

Normally the Xmas Three is connected by a flange or clamp to the top of the wellhead.

2/19/2014

9

4. Packers

It provides physical isolation of the casing/tubing annulus above the production zone.

Provide well protection Corrosion protection Abrasion protection Casing/wellhead burst protection

Production stability Production annulus heading


Packers

Zonal Isolation Selective or segregate production

Annulus to Tubing InjectionGas lift or chemical

Injection OperationsEconomic injection rate or fracturing

Temporary IsolationBridge plug


2/19/2014

10

Packers


Packers have four key features:1. Slip2. Cone3. Packing-element system4. Body or mandrel.

The slip device penetrate and grip the casing wall when the packer is set.

The cone drives the slip outward and into the casing wall when setting force is applied to the packer.

Once the slips have anchored into the casing wall, additional applied setting force energizes the packing-element system and creates a seal between the packer body and the inside diameter of the casing.

Packer Classifications


Permanent Packer Permanent packers difficult to remove and it can be removed

from the wellbore only by milling. Retrieval is usually accomplished by some form of tubing

manipulation The permanent packer is fairly simple and generally offers higher

performance in both temperature and pressure.

Retrievable Packer The retrievable packer may or may not be resettable, but

removal from the wellbore normally does not require milling. The retrievable packer can be very basic for low pressure/low

temperature (LP/LT) applications or very complex in high pressure/high temperature (HP/HT) applications.

This packer will invariably cost more with the same quality of permanent packer

2/19/2014

11

Packers Selection

Casing and tubing size Depth of the well and bottom-hole pressure Annular fluid type and differential pressure Extent of thermal stress and potential forces Need for tubing retrieval without the packer Bore size offered by the packer Completion string equipment compatibility The deviation angle, effect on setting mechanism


5. Nipple and Mandrel Systems Applications

Isolation and plugging of the tubing string for well shut in, workover, or hydraulically setting packers.

A ported device for communication between the tubing and the annulus.

Emergency closure of the tubing or annular flow

Installation of downhole pressure and temperature recording gauges.


2/19/2014

12


6. Sub Surface Safety System

They are required forX-mas tree removal for workoverRemoval of surface valvesDamage to X-mas tree Leakage on X-mas tree

SSSV are available besed onDirect control (D.C. SSSV)Remotely of Surface contro (S.C. SSSV)


2/19/2014

13

Directly Controlled (D.C. SSSV)

Differential pressure operated safely valves Ambient or pre-charged type safety valves Advantages

Simple construction and operating principle Easy installation and retrieval Cheaper installation cost

Disadvantages Not 100% reliable Performance could be affected due to solid

deposition Testing of valve operation is not easy


Surface Controlled (S.C. SSSV)

Held open by hydraulic pressure Either ball or flapper type Tubing or wireline retrievableTubing retrievable must be

reliableTubing retrievable offer larger

flow area


2/19/2014

14

7. Tubing-Annulus Communication Equipment

The communication (circulation) is required for: To displace out the tubing contents to initiate

production To displace tubing contents with a kill fluid To allow continuous or intermittent injection:

Corrosion or scale inhibitor Gas for gas lift

Available options are: Sliding side door or sliding sleeve Side pocket mandrel


Sliding side door

A completion device that can be operated to provide a flow path between the production conduit and the annulus. Sliding sleeves incorporate a system of ports that can be opened or closed by a sliding component.


Is it this?

2/19/2014

15

Side Pocket Mandrel

A completion component that is used to house gas-lift valves and similar devices that require communication with the annulus.

The design of a side-pocket mandrel is such that: the installed components do not

obstruct the production flow path enabling access to the wellbore and

completion components below. Consists of a tubing mandrels with ports

located on its outside wall



Running Procedures

2/19/2014

16

THANK YOU

completion equipments

Documents

new spool

tubing maximum

single spool

metalwell design

surfacewell design

wellhead systemswell

internal pressure metal

casing strings