This document discusses blowout preventers (BOP) stack components and types, focusing on their classification, specifications, and operational requirements in drilling. It outlines various BOP types, including annular and ram-type preventers, along with their functions, maintenance, and safety standards for different rig types. Additionally, it provides recommendations for stack requirements based on pressure ratings and operational contexts, emphasizing safety and efficiency in blowout prevention.

1. Blowout Preventers BOP Stack Components & Types
December 23, 2017Drilling Manual
Blowout Preventers (BOP) Stack is used to seal the wellbore and thereby contain a kick (
check drilling kick). Two main types of BOP preventers are in use in the industry (both
types are discussed below). In this article, we shall discuss its BOP blowout preventers
stack classification, components & types.
Contents hide
1 API Classification For BOP Blowout Preventers Components
1.1 API Codes For BOP Stack Components
1.2 How To Specify BOP Stack
1.3 BOP StackArrangements
2 BOP Blowout Preventers Types
2.1 Annular Preventers Type
2.2 Ram Type Preventers
2.3 Variable Bore Rams Type
2.4 Blind & Shear Rams Type
3 BOP Blowout PreventerSpare Parts
4 Drilling Spools
5 ENI Recommendations For BlowoutPreventers BOP Stack Operations
5.1 BOP BlowoutPreventers For Land Rigs, Jack-UpsAnd Fixed Platform
5.1.1 The minimum BOP stack requirements are as follows:
5.1.2 Pipe Rams
5.1.3 Rig Site Maintenance
5.1.4 Choke & Kill Lines
5.2 BOP BlowoutPreventers For Floating Rigs
5.2.1 The minimum BOP stack requirements forfloating rigs are as follows:
5.2.2 Pipe Rams
5.2.3 Choke & Kill Lines
5.3 Deep Water Operations
5.4 Share this:
API ClassificationFor BOP Blowout Preventers
Components
API classification for BOP blowout preventers equipment is based on working pressure
ratings. BOP stacks are rated to 2000 (2m), 3,000 (3m), 5,000 (5m), 10,000 (10m), or
15,000 (15m) psi.
API Codes For BOP Stack Components
As we mentioned, blowout preventer stacks are rated to 2000, 3,000, 5,000, 10,000, or
15,000 psi. A preventer stack normally consists of an annular preventer on top, followed by

2. one or more (typically up to three) ram-type preventers (Fig.1). The inclusion of a full-bore
drilling spool makes it possible to connect the kill and choke lines (Adams 1979b, 1980a).
Fig.1 BOP
Blowout Preventers Stack Arrangement
 A= annular type blowout preventer.
 G= rotating head.
 R=single ram-type preventer with one set of rams, either blank or for pipe, as the
operator prefers.
 Rd = double ram-type preventer with two sets of rams positioned according to
operator’s choice.
 Rt = triple ram-type preventer with three sets of rams positioned according to
operator’s choice.
 S =drilling spool with side outlet connections for the choke and kill lines.
 M = 1000 psi rated working pressure.
How To Specify BOP Stack

3.  Components are listed reading upward from the uppermost piece of permanent
wellhead equipment, or from the bottom of the BOP blowout preventers stack.
 A blowout preventer stack may be fully identified by a very simple designation, such
as:
5M -13 5/ 8 – SRRA
This preventer stack would be rated 5000 psi working pressure, would have an internal
bore of 13 5 /8 inches, and would be arranged as in the below Figure
Fig.2
BOP Stack Arrangements
BOP blowout preventers stack arrangements other than those illustrated may be equally
adequate in meeting well requirements and promoting safety and efficiency.

4. Fig.3

5. Fig.4

6. Fig.5
An important consideration for the design of the BOP blowout preventer stack
arrangement is the space it occupies under the rig. Even after setting multiple casings (with
each casing head adding to the total height of the equipment), it still must be possible to
accommodate the full preventer stack.
BOP Blowout Preventers Types
AnnularPreventers Type
This type of preventer is able to seal around any object with a circular (or nearly circular)
cross-section as well as over an empty hole. This means that it can also seal around kelly
(hexagonal shapes are better than square shapes). Because of its variable diameter, it also
allows tool joints to pass when the pipe is being lowered into the hole while surface
pressure is present, an operation called stripping (check also well control stripping
procedure) (overcoming the pressure area forces with the pipe weight)

7. or snubbing (forcing the pipe into the hole because the weight is not enough to overcome
the pressure area forces) (Fig.6).
Fig.6 Annular Preventers
Operating pressure is generally lower than that used for ram-type preventers because the
piston area is far larger. The pressure can also be adjusted to ease the passage of the
tubular while stripping into the well by reducing friction. Still, it is necessary to lubricate
the pipe while stripping it into the well. Drilling mud or water can be used for lubrication.
The operating principle of this type of preventer is simple. Hydraulic pressure is applied to
the low side of a wedge-shaped piston. The circular wedge then forces the sealing element
toward the inside. Frequent closing and opening of the sealing element will significantly
shorten its life. In particular, closing over an empty hole has an adverse effect on the
sealing element. For this reason, it is common not to test annular preventers as often as
ram-type preventers.
Ram Type Preventers
Rams are found on most BOP blowout preventers stacks, except in some low-pressure
applications. They are closed by hydraulic pressure, which forces the set of rams together
from both sides. As a backup measure, they can also be manually closed (Fig. 10.7).

8. Sealing is achieved between the upper surface of the ram and the preventer body and
between the sealing surfaces of the ram. Different kinds of rams are available. Pipe rams
have a semicircular groove that enables sealing around the pipe. They are designed for
sealing around a specific diameter of the pipe. Therefore, changing the rams can be
necessary when switching to a different-diameter drill pipe or closing in a well with drill
collars or casing (or other equipment) within the preventer stack. Furthermore, while
shutting in the well, no tool joints should be located within the BOP blowout preventers
stack. This is easily avoided by lowering or lifting the top tool joint of the drill string to an
easily accessible working height at the rig floor.
Most modern ram-type preventers have a built-in secondary seal consisting of a plastic
sealing material that is forced against the sealing surfaces by twisting a bolt. This seal is
designed as a contingency measure in case the ram preventer starts to leak during a well-
control operation (Adams 2005).
Ram type preventers should be equipped with extension hand wheels hydraulic
locks.
Variable Bore Rams Type
The variable-bore rams type are available with flexible steel fingers that can seal around
pipe diameters smaller than that of the ram itself. With a standard pipe ram, it is possible to
hang a drill string on the ram. A variable-bore ram, on the other hand, is not strong enough
to support a drill string.
Blind & ShearRams Type
Blind rams type are used to seal over an open hole. They have a sealing surface that is
pressed together when actuated. A special kind of blind ram is called a shear ram. Blind

9. shear rams have cutting edges and are able to shear through drill pipe (and small-
diameter drill collars) and seal over it. Because this option eliminates the possibility of
circulating through the drill pipe, the shear ram is considered an option of last resort.
Typically these are used offshore.
BOP Blowout Preventer Spare Parts
The following recommended minimum BOP blowout preventers spare parts approved for
the service intended should be available at each rig:
1. A complete set of drill pipe rams and ram rubbers for each size drill pipe being used,
2. A complete set of bonnet or door seals for each size and type of ram preventer being
used,
3. Plastic packing for BOP blowout preventers secondary seals,
4. Ring gaskets to fit flange connections, and
5. Appropriate spare parts for annular, when used.
When storing blowout preventer metal parts and related equipment, they should be
coated with a protective coating to prevent rust.
Drilling Spools
While choke and kill lines may be connected to side outlets of the BOP blowout preventers
stack, many operators prefer that these lines be connected to a drilling spool installed
below at least one preventer capable of closing on pipe. Utilization of the blowout BOP side
outlet reduces the number of stack connections by eliminating the drilling spool and
shortens the overall height. The reasons for using a drilling spool are to localize possible
erosion in the less expensive spool and to allow additional space between rams to facilitate
stripping operations.
According to API, drilling spools should meet the following minimum specifications:
1. Have side outlets no smaller than 2″ nominal diameter and be flanged, studded, or
clamped for API Class 2M, 3M, and 5M. For
2. API Class 10M and 15M installations should have a minimum of two side outlets,
one 3″ and one 2″ nominal diameter.
3. Have a vertical bore diameter at least equal to the maximum bore of the uppermost
casing head.
4. Have a working pressure rating equal to the rated working pressure of the attached
blowout preventer.

10. ENI Recommendations For Blowout Preventers BOP
Stack Operations
In my point of view, Eni presented a good and useful considerations while blowout BOP
Design & Operations which are as following:
BOP Blowout Preventers For Land Rigs, Jack-Ups And Fixed Platform
The pressure rating requirement for blowout BOP equipment is based on the ‘maximum
anticipated surface pressure. Projects that require a different working pressure in the
whole system shall be agreed upon by the Company and Drilling Contractor.
The minimum BOP stack requirements are as follows:
Firstly, A 5,000 psi WP stack should have at least:
 Two ram-type preventers (one shear ram and one pipe ram).
 One 2,000 psi annular type.
Secondly, A 10,000 psi stack should have at least:
 Three ram-type preventers (one shear ram and two pipe ram).
 One 5,000 psi annular type.
Thirdly, A 15,000 psi stack should have at least:
 Four ram-type preventers (one shear ram and three pipe ram)
 One 10,000psi annular type.
Pipe Rams
 While drilling, all pipe ram preventers shall always be equipped with the correct
sized rams to match the drill pipe being used. If a tapered drill string is being used
e.g. 3 ” and 5”, one set of rams will be dressed to match the smaller drill pipe size.
During casing jobs or production testing, the choice of pipe rams shall be defined by
the Company, depending on the external diameter(s) of the casing/drilling/testing
string(s) in the operation and blowout BOP stack composition.
 At least one ram preventer, below the shear rams, shall be equipped with fixed pipe
rams to fit the upper drill pipe in use. The minimum distance between shear rams
and hang-off pipe rams shall be 80cm (30”).
 The use of variable bore rams (VBRs) is acceptable but they should not be used for
hanging off pipe which is near to the lower end of their operating range.

11. Rig Site Maintenance
Rig site repair of BOP equipment is limited to replacing worn or damaged parts. Under no
circumstances is welding or cutting to be performed on any BOP equipment. Replacement
parts should only be those supplied or recommended by the equipment manufacturer.
Choke & Kill Lines
 Each choke and kill line BOP outlet shall be equipped with two full bore valves, the
outer valve of which will be hydraulically operated (preferably fail-safe closed).
 The minimum diameter of the choke line will be 3″ ID, while the kill line should have
not less than a 2″ ID. Articulated choke lines (Chiksan) are not acceptable unless
derogation is agreed for a particular application.
 A number of various arrangements in the position of the choke and kill line outlets
are used in blowout BOP stack configurations throughout the oil industry. The rig
operating manual should highlight these variations, their limitations, and all the
potential uses of a particular layout.
 On a four ram BOP stack, Eni-AGIP recommends that the positioning of choke and
kill line outlets below the lowest pipe rams be avoided as these are like the last
resort ‘Master Valve’ of the BOP stack.
 The inclusion of shear rams requires the choke and kill lines positions to be such
that the direct circulation of the kick, through the drill pipe stub after shear rams
activation, can be performed with the drill string hang-off on the closed pipe rams
and holding pressure.
BOP Blowout Preventers For FloatingRigs
The minimum BOP stack requirements for floating rigs are as follows:
Firstly, A 10,000 psi stack should have at least:
 Four ram type preventers (one shear ram and three pipe rams)
 One or preferably two 5,000psi annular type preventers (one annular retrievable on
Lower Marine Riser Package).
Secondly, A 15,000 psi stack should have at least:
 Four ram-type preventers (one shear ram and three pipe rams)
 Two 10,000 psi annular type blowout preventers (one annular retrievable on the
Lower Marine Riser Package).
b) The upper hydraulic connector shall have a pressure rating equal to or exceeding the
working pressure of the bag type preventers.

12. Pipe Rams
Any type of blowout preventer stack will contain pipe rams that are able to close on every
size of drill pipe/tubing that will be run through the stack. The use of VBRs is acceptable
but they should not be used for hanging off pipe which is near to the lower end of their
operating range. At least one ram preventer below the shear rams shall be equipped with
fixed pipe rams to fit the upper drill pipe in use. The minimum distance between shear
rams and hang-off pipe rams shall be 80cm (30”).
Choke & Kill Lines
Each choke and kill line BOP outlet shall be equipped with two fail-safe, remotely
controlled gate valves, rated to the BOP working pressure. The valves shall be fail-safe in
the closed position.
The minimum diameter of choke/kill lines will be 3″ ID. The function of each line must be
interchangeable at the surface to be able to line up with both the rig pumps and the choke
manifold.
A number of various arrangements in the position of choke/kill line outlets are used in BOP
stack configurations throughout the oil industry, The rig operating manual should highlight
these variations, their limitation and all the potential uses of the particular Layout.
The inclusion of shear rams requires choke and kill line positioning such that the direct
circulation of the kick, through the drillpipe stub after shear rams activation, can be
performed with the drill sting hang-off on closed pipe rams holding pressure. Eni-Agip
recommends that choke and kill line outlets are positioned above the lowest pipe rams as
these are the like the last resort ‘Master Valve’ of the blowout BOP stack.
Deep WaterOperations
For deepwater operation, it is recommended to use a BOP stack equipped with an injection
line to pump methanol or glycol, in order to reduce the likelihood of hydrates forming
during well control operations. It is also recommended that pressure and temperature
gauges are located on the blowout BOP stack.
Ref: Applied Drilling Engineering, Eni Drilling Operations Manual, Aramco Drilling
Manual 2006