Post on 24-Mar-2018
1
Black Gold Innovations co. is an oilfield, product, equipment and service Company
providing high quality cost-effective engineered well completion equipment and services to
the oil and gas industry in the Iran and select international markets. Recruiting skilled and
proficient engineers that have been worked in various well completion industries for years,
this company has been acquired the technology of and domestic design production of
downhole completion equipment for oil and gas wells.
Black Gold provides for customers comprehensive range of fully integrated “Completion
Systems,” which package and integrate equipment, products, processes, procedures and
programs to provide a combination of best-in-class and fit-for-purpose products and services.
BGI co. has been recruited specialists in design, manufacturing, quality control, project
control and planning and is ready to supply complete downhole completion equipment in
highest quality.
Though the main range on productions of the company consist of both Baker and Halliburton
types, Black Gold also is ready to provide other types of completion equipment in the same
class. In order to provide Localized and fit-for-purpose production that meets customer needs,
BGI design team is qualified to redesign available productions to acquire specific technical
requirements in functioning, strength and corrosion resistance performance, as well as to
preserve the consistency and interoperability with other original types.
INTRODUCTION
2
The Fluted Swages / Adapters are customer specified threaded adapters of
short length which are run between tubing joints to protect down-hole
control lines and electrical cables as well as to centralize the string in the
well.
There are six axial slots on the equipment’s body to place control line at
suitable angle and fix it to the string above the subsurface safety valve
landing nipple up to the surface. Tool’s drift ID is the same as tubing’s and
the OD is slightly smaller than casing drift size. Fluted design allows fluid
circulation to be performed properly.
Features
6 slots at every 60o ensures control line protection in every fastened
angle
Well-finished and smooth internal diameter
Available in customer-specified thread
Tubing
Size
Casing
Size
Casing Weight
(PPF)
Max.
OD.(in)
Drift Size
(in)
Pressure
Rating
(psi)
Product No.
5” 7” 29 6.000 4.256 7000 BG-100-5000
7” 95/8
” 36-47 8.500 6.164 5000 BG-100-7000
Fluted Swage / Fluted adapter
3
Flow Couplings are used in the tubing string of a flowing well, in conjunction with
Nipples, Safety Valves, or Sliding Sleeves, to protect the tubing from abrasive action
caused by turbulent flow through restricted areas. As a general rule, a Flow Coupling
should always be used when the flow control device is installed on a permanent
basis, i.e., on a safety valve. The Flow Coupling, while normally run immediately
above a Nipple, Safety Valve or Sleeve, may be run both above and below, to assure
increased protection below the restricted flow area.
Flow Couplings are available in 3 to 20 foot lengths, adequately covering the area
most generally affected. Couplings are manufactured in either alloy steel heat-treated
for maximum erosion resistance, and strength, (Hardness 30-36 RC, 110,000 MYS)
or from alloy steel or stainless steel heat treated for maximum corrosion resistance,
based on NACE Specifications. (Hardness is 18-22 RC, 80,000 MYS) Flow
Couplings are available with special outside diameters or threads, upon request.
Features
Extra smooth Inner Diameter diminishes erosion and corrosion imposed by
turbulent flow
Available in various length, material and thread upon request
Tubing
Size
Max. OD.
(in)
Drift Size
(in) Connection
Pressure
Rating (psi) Product No.
5” 5.625 4.256 NEW VAM 5” 18#
BOX x PIN 7000 BG-120-5000
7” 7.720 6.164 NEW VAM 7” 29#
BOX x PIN 5000 BG-120-7000
Flow Coupling
4
Safety valve landing nipples are installed integral to the tubing string and provide a means of
locating and locking a wireline retrievable safety valve in place. The wireline retrievable
safety valve (WRSV) is locked in place by using the locking profile integral to the landing
nipple.
The safety valve landing nipples are ported for control line fluid communication from the
surface to operate a down-hole safety valve. The landing nipples are also
designed to withstand loads from the tubing string to ensure long-term
reliability of the safety valve system.
Features
Robust control line connection - metal-to-metal jam nut ensures
reliable sealing
Eccentric control line lug - machined control line inlet protects the
control line while installing
Large bore design - allows access to lower completion by offering a
full bore ID
Tubing Size Seal Bore
Size (in) Max. OD
Pressure
Rating (psi)
Port Size
(in) Product No.
5” 3.812 5.787 7000 0.250 BG-180-3812
7” 5.950 8.267 5000 0.250 BG-180-5950
Safety Valve Landing Nipple
5
The BGI’s Wireline Retrievable Safety Valve is a self-equalizing, flapper-type, surface-
controlled, subsurface, wireline safety valve. The wireline valve incorporates a modular
concept to allow flexibility and adaptability to existing and new completions. BGI safety
valves may be supplied with a BGI lock mandrels, or as a subassembly with adapter to a
standard lock. When safety valves are assembled to a safety valve lock, the model
designation is expanded to include the lock and the safety valve nipple into which it is
landed. The Safety Valve Lock must be compatible with the Nipple Profile.
When properly installed, the valve is hydraulically controlled from the surface via a
stainless steel control line that connects the Landing Nipple to the surface Emergency
Shut Down System. Loss of control line pressure will close the valve and shut-in the
well.
Features
Strong and reliable closure system
Solid construction flapper made from high strength and corrosion resistant
material
Spherical radius seat on flapper improves metal-to-metal seal reliability
Low pressure sealing is acquired in closed position by Resilient seal system
Equalizing system ensures easy opening process
Low-friction sealing system facilitates both opening and closing cycles
Manufactured from Highly resistant material this product is fully fitted for sour
service
High pressure – high temperature service is available by reliable packing system
Tubing
Size
Seal Bore
Size (in)
Drift
Size (in)
Max.
Setting
Depth
(ft)
Opening
Pressure
(psi)
Pressure
Rating
(psi)
Temperature
Rating (C) Product No.
5” 3.812 2.126 1000 1200 +
shut-in
pressure
6000 20 - 200 BG-220-3812
7” 5.950 3.267 1000 6000 20 - 200 BG-220-5950
Sub-Surface Safety Valve
6
The Expansion Joints are designed to be used in single and dual - string
completion to accommodate changes in tubing length caused by variations in
pressure, temperature or both. They are capable of maintaining the pressure
integrity of tubing while allowing the string to safely expand and contract. The
Expansion Joint can be run above Packers. The proper placement and stroke
selection of these splined slip joints reduce the chances of over stressing the well
tubing during production, acidizing, fracturing and other well operations. Alloy-steel
construction gives these joints high body and end-connection tensile strength. Stroke
length may be changed in the field. The splines transmit torque through the joint.
The travel joint consists of a top sub, outer mandrel, inner mandrel and shear sleeve.
The packing stack is retained by the retainer cap. An o-ring is installed in the top
sub. Sheer pins hold the travel joint in the fully ex tended, closed or partially open
condition and at one foot interval. The travel length of the joints can be 10ft or 20ft.
Features
Maintains pressure integrity during expansion and contraction
Adjustable shearing value
Adjustable pinned length at intervals of 1 ft
Tubing Size Maximum
OD (in)
Drift ID
(in)
Pressure
Rating(psi)
Temperature
Rating(C) Product No.
41/2
” 5.740 3.900 5000 20 - 150 BG-250-4500
51/2
” 7.690 4.758 5000 20 - 150 BG-250-5500
Expansion Joint
7
The side pocket mandrel is made up as an integral part of the production tubing
when preparing a well for gas lift, chemical injection, waterflood or other special
applications. This mandrel is designed to be installed in straight hole wells. BGI’s
side pocket mandrels are designed with a round cross-section body and are
available in a variety of tubing threads and sizes for installation as part of the
tubing string. Standard non-orienting kickover tools are utilized in this mandrel to
install and retrieve flow control devices by standard wireline methods.
The side pocket mandrel’s tubular pocket consists of a locking recess located
below a top no-go and two polished bores straddling ports which provide
communication between the casing annulus and the tubing. The wireline flow
control devices have packing which seal in the polished bores above and below the
ports in the mandrel pocket.
Features
Each side pocket mandrel is inspected and tested under the guidelines of a
Quality Assurance Program which includes wet magnetic particle
inspection, hardness value test, hydrostatic pressure test and ID/OD drift.
All mandrels are made from fully traceable material.
Compatible with other manufacturers' flow control devices.
Tubing
Size
Max. OD
(in)
Drift Size
(in)
PocketSize
(in)
Pressure
Rating Product No.
41/2
” 5.984 3.793 1.000 5000 BG-280-4500
51/2
” 7.755 4.638 1.500 5000 BG-280-5500
Side Pocket Mandrel
8
Sliding Side Door (SSD) is a downhole equipment that allows communication
between the tubing and annulus for circulation or selective-zone production. The
BGI’s SSD is high performance, Non-elastomeric equalizing sliding sleeve. When
desired, the sleeve can be shifted open or closed using standard wireline methods and
equipment. The tool is designed such that any lock profile and compatible seal bores
can be specified and ordered to accept a wide range of Wireline Locks, and
accessories. The sleeve is available in downshift-to-open or upshift-to-open versions.
Features
A specially designed Diffuser Ring made of high-strength thermoplastic is
critically spaced between the flow ports and the upper packing unit. This
prevents damage to the upper packing unit during shifting by controlling the
rush of fluid or gas, and lessens the likelihood of tool string damage by
providing for slow equalization of high differentials upto 1500 psi.
The seal stack is manufactured from high-strength, non-elastomeric
compounds that are chemically inert. Rather than becoming hard and brittle or
bonding to the metal, as is the case with elastomeric materials, our seal
compound actually behaves as a lubricant, alleviating seal bonding problems.
Mill slots replace drill holes as flow ports on both the housing and the insert to
allow more flow area, reduce erosion and allow higher torque and tensile
strengths through the sleeve.
Locating the threaded connection inside the primary seal stack eliminates the
need for Oring thread seals and cuts the number of potential leak paths in half.
A locking, angled torque shoulder replaces traditional square shoulder to allow
higher torques and reduce thread back-off.
Tubing
Size
Max.
OD.(in)
Drift Size
(in)
Profile Size
(in)
Pressure
Rating (psi)
Temperature
Rating (C) Product No.
41/2
“ 5.500 3.785 3.688 6000 20-200 BG-300-4500
51/2
” 6.500 4.677 4.562 6000 20-200 BG-300-5500
Sliding Side Door
9
The anchor tubing seal assembly is used as an alternative to set-down weight; it
prevents seal movement or is used when it is preferable to land the tubing in
tension. The anchor tubing seal assembly is run in on the production string. Set-
down weight causes the anchor's threaded latch to engage the corresponding threads
in the top of the packer. Once engaged, the anchor and tubing are securely locked in
place. Any tubing contraction will cause a tensile load to be applied to the tubing
string. Care must be taken to ensure tensile forces that develop will not part the
tubing whenever an anchor is used. To release the anchor, it must be rotated to the
right 10 to 12 turns at the packer.
Features
A solid nut anchor with special 2 TPI left hand square thread creates a metal
to metal seal with the packer when sufficient set down is applied.
High Quality Seals has been adopted for high pressure / high temperature
conditions
Premium thread has been utilized instead of O-ring in extension
Casing Size
Casing
Weight
(lb/ft)
Maximum
OD (in) Drift ID (in)
Pressure
Rating(psi) Product No.
7” 29 5.000 3.250 5000 BG-320-7000
95/8
” 36-47 6.910 4.850 5000 BG-320-9625
Anchor Seal Assembly
10
The BGI packer is a hydraulically set permanent packer that features the largest
possible bore through combined packer and seal accessory. This Packer is run to
depth, connected to the tubing with a compatible Anchor Seal and set by applied
tubing pressure. This makes the packer ideal for use in high angle deviated wells.
The packer comprises an upper seal bore with a left hand square thread, a high
pressure/high temperature Aflas packing element system, straddled by upper and
lower slip rings, and a setting piston. A solid nut anchor with nose seal provides a
metal to metal seal between the production tubing and the packer when sufficient set
down load is applied. An chevron seal stack backs this seal up and operates when
insufficient set down load is applied to effect a metal to metal seal.
Features
The packing element is resistant to swabbing which enhances reliability and
allows increased running speed.
Two opposed sets of full circle slips allow the load to be distributed evenly
around the casing wall and ensure the packer remains where it was set.
Interlocked expandable metal back-up rings contact the casing and create a
positive barrier to packing element extrusion.
All O-rings sealing tubing to annulus are supported by back-up rings to
improve long term seal integrity.
A guide is furnished as standard equipment allowing the attachment of a mill-
out extension, seal bore extension or other component below the packer.
The packing element system consists of a single piece packing element design
that is self-energized from the initial set condition. The standard element has a
hardness of 80° durometer which is suitable for temperatures up to 400° F.
Higher durometer material can be used for higher temperatures combined with
high pressures.
Casing
Size
Casing Weight
(lb/ft)
Maximum OD
(in)
Drift ID
(in)
Seal Bore
(in)
Pressure
Rating(psi) Product No.
7” 29 5.875 3.875 4.750 5000 BG-340-7000
95/8
” 36-47 8.125 4.875 6.500 5000 BG-340-9625
Permanent Packer
11
A mill-out extension can be run directly below a seal bore packer or seal bore extension. For
permanent packers, the mill-out extension is required to accommodate the mandrel and catch
sleeve of the packer milling tool during packer milling. In the case of a retrievable seal bore
packer, the mill-out extension will accommodate the mandrel and catch sleeve of the
retrieving tool.
Tubing
Size
Max. OD.
(in)
Drift
Size (in) Connection
Pressure
Rating
(psi)
Product No.
5” 5.039 4.151 NEW VAM 5”
18# PIN x PIN 7000 BG-360-5000
7” 7.039 6.060 NEW VAM 7”
29# PIN x PIN 5000 BG-360-7000
Cross over is used in the well completion string to connect different size or thread
connection completion items. Using this equipment, it is possible to change
completion size along the string. It is also used to connect equipment in various
thread type and size to the completion string.
Mill-out Extension
Cross over
12
BGI No Go Nipples are downhole tubing nipples that provide for the location of various
wireline flow control devices in the production string. The location and number of Top No-
Go Seating Nipples should be carefully considered in the completion planning stages to allow
maximum versatility in the positioning of various flow control devices. Nipples contain a no-
go shoulder used to locate and set the flow control device being run into the well.
Top No-Go Seating Nipples may be used for the following operations:
Land blanking plugs to shut in or test the production tubing.
Land velocity type safety valves (SSCSV).
Land equalizing check valves.
Land circulating blanking plugs.
Land chokes to reduce surface flow pressure or to have pressure drops downhole to
prevent surface freezing in gas production.
Land instrument hangers with geophysical devices such as pressure and temperature
recorders.
Features
Working pressures to 7,500 psi.
Honed sealing bores for maximum sealing performance.
Tubing Size Seal Bore
Size No-Go ID
Pressure
Rating Product No.
41/2
” 3.125 3.210 7500 BG-380-3125
3.312 3.395 7500 BG-380-3312
51/2
” 4.125 4.210 7500 BG-380-4125
4.312 4.400 7500 BG-380-4312
Top No Go Nipple
13
The BGI lock mandrel is a top no-go style lock. With a no-go shoulder located just below
the locking dogs, this lock will land and lock flow control devices in the corresponding
seating nipples. Lock selection should be compatible with the size and model designation
(based on designed pressure rating) of the selected seating nipple. BGI’s Locking
Mandrels are fully compatible with Baker’s Model “AF” No-go Nipples and can be run
with a Model “A” Running Tool and model “D” Probe.
Features
Simple and rugged construction
Locking mechanism in located above the seating elements, therefore no O-rings
are required
Smooth bore through the lock does not subject the operating mechanism to
corrosion or sticking by foreign materials
Running tool gives a positive indication that lock is set in the nipple and that the
locking operation is complete
The lock and running tool are compatible with normal wireline equipment and
procedures
Seal Bore Size
(in)
Fishing Neck
Size (in) No-Go OD (in)
Pressure Rating
(psi) Product No.
1.875 1.380 1.935 10000 BG-400-1875
3.125 2.620 3.200 10000 BG-400-3125
3.312 2.620 3.375 10000 BG-400-3312
3.688 3.120 3.740 10000 BG-400-3688
3.812 3.120 3.870 10000 BG-400-3812
4.125 3.120 4.200 10000 BG-400-4125
4.312 3.120 4.390 10000 BG-400-4312
4.562 4.000 4.650 10000 BG-400-4562
5.950 4.250 6.020 10000 BG-400-5950
Lock mandrel
14
Bypass Blanking Plug with removable mandrel is a positive blank-off device designed to seal
off pressure from above and below. These plugs are for use in wells where sand
or sediment might be encountered. The plugs have a removable mandrel which
protrudes from the fishing neck of the lock so that a sand bailer can expose it for
retrieval. This Plug may be used with either the top no-go or bottom no-go type
locks.
The plug, with the selected lock attached, is run in and set without the removable
mandrel in place, thus, providing a large fluid bypass area and allowing fast run-
in time. The mandrel is then run in and landed inside the plug, blanking off the
bypass ports. Equalization is accomplished by pulling the removable mandrel
from the plug and opening the bypass ports to pressure. The plug itself is then
pulled using conventional running and pulling tools.
Features:
Optional internal fishing neck can be provided for the removable
mandrel. This allows the operator to retrieve the removable mandrel with
the same tool as the lock.
The two-trip system is suited for sandy service. By retrieving the
mandrel, the flow through ports help clean up debris.
Equalizing ports must be opened before access to the fishing neck can be
obtained.
Can be ordered with chevron seals on the removable mandrel for temperatures to
450°F.
Seal Bore Size Fishing Neck
Size (in)
Pressure Rating
(psi)
Temperature
Rating (C)
Product No.
1.875 1.380 10000 20 - 170 BG-420-1875
3.312 2.620 10000 20 - 170 BG-420-3312
3.688 3.120 10000 20 - 170 BG-420-3688
3.812 3.120 10000 20 - 170 BG-420-3812
4.312 3.120 10000 20 - 170 BG-420-4312
4.562 4.02 10000 20 - 170 BG-420-4562
Bypass Blanking Plug
15
Separation Sleeve when attached to an appropriate lock is a wireline retrievable tool
used to isolate the control line port of Safety Valve Landing Nipple. Its packing units
are placed in upper and lower sealbore and prevent wellbore pressure and
contaminants to pass through the control line. Separation Sleeve also has a nipple
profile and polished bore to place blanking plug during the completion tests.
Instrument Hangers are utilized to land and lock geophysical instruments in the string. It is
attached to a lock mandrel and is placed in a compatible seating nipple.
Features
Simple and rugged construction.
Positive indication the Instrument Hanger Adapter is set.
Tubing Size Seal Bore Size (in) Profile Size (in) Pressure
Rating (psi) Product No.
5” 3.812 1.875 6000 BG-440-3812
7” 5.590 3.812 6000 BG-440-5950
Separation Sleeve
Instrument hanger
16
Running tool is used to run and set locking mandrels. BGI’s Running Tool is designed to
prevent accidental setting even if tight spots are encountered while running in the well. The
running tool and lock will not separate until the locking dogs on the locking
mandrel are fully expanded into the nipple locking profile. If this does occur,
the running tool will not release and will bring the lock back out of the well
when retrieving the running tool. Once the lock sets inside the nipple, the
running tool dogs retract and release the fishing neck. The running tool returns
the surface after shearing the pin in the extension probe leaving the lock
securely in the seating nipple. BGI’s running tool is fully compatible with
Baker’s Model “AF” locks
Features:
Simple design
Running tool cannot release from lock mandrel unless property set in
its mating profile
Tell-tale ring provides positive indication of successful lock setting
Minimal running and retrieving tools requirement
Several lock sizes can be run with same running tool.
Running tool simply constructed–no collets, springs, or plunger to
move up or down to manipulate lock into a locating position.
Running tool is in accordance with accepted wireline procedures.
The running tool has its own smaller set of locking dogs which hold on
to the lock until it is securely set in place.
The running tool takes the guesswork out of the process. Either the lock
is set properly, or the entire lock comes back out of the hole with the
running tool.
Running Tool
17
Running/Pulling Tool is a basic wireline device which connects a wireline tool
string to a wireline retrievable flow control device that is to be run into or
retrieved from a well. This Running/ Pulling Tool is designed to engage an
internal type fishing neck. The tool is offered in a wide range of sizes.
The Running/Pulling Tool consists of a cylinder which is fitted with a number of
Dogs mounted on a spring loaded Retainer. A Core is located concentrically
between the Dogs, Dog Retainer, Dog Spring and Dog Spring Retainer. The
Top Sub screws into the Cylinder and retains the Cylinder Spring between the
top of the Dog Spring Retainer and the bottom of the Top Sub. The Core is
fixed to the Top Sub by means of a Shear Pin. A threaded Fishing Neck is
screwed onto the Core. As the Core enters the fishing bore, the dogs are pushed
upwards and are moved off the tapered shoulder of the core allowing them to
retract, until they reach the latching groove in the bore of the internal Fishing
Neck. Then the springs push the dogs back into place on the tapered shoulder
locking the tool into place. The act of shearing the pin permits the axial
movement between the core and the cylinder and causes the dogs to move off
the tapered shoulder of the core. This action allows the dogs to collapse and
releases the tool from the downhole device.
Features:
Easy retrieving system
Can be utilized as running tool as well as pulling tool
Compatible with various types of lock mandrels
Can be utilized for pulling out subsurface safety valves using X-prong Extension
Running/Pulling Tool
18
Positioning tools are used to move the inner sleeve to its open or closed position
in Sliding Side-Door circulating devices. The positioning tool engages the
recess in the upper (or lower) end of the inner sleeve to permit the sleeve to be
shifted by a jarring action. The tool is designed to release itself only after the
sleeve reaches its fully open or closed position. This automatic-releasing
feature incorporates a releasing profile on the key itself that acts to compress
the key spring and release the positioning tool. A shear pin is an added feature
designed to release the tool in the event well conditions make it impossible to
shift the sleeve.
Features
Automatic locating
Proof of completed shift
Adjustable shear release values
Emergency release feature
Common thread connection – allows any combination of wireline
prohibitive tools to be attached to it
Positioning Tool
19
The Wireline Retrievable Injection Pressure Operated Gas Lift Valve is a 1 or 1.5
inch OD valve primarily controlled by injection gas pressure. The valve is used to
control gas pressure and its flow from the casing annulus into the tubing during gas
lift operations.
This valve consists of a tail plug, bellows assembly, bellows housing, stem with
tungsten carbide ball, seat housing with a floating seat, packing retainer and check
nose with reverse flow check dart. The valve is available in either stainless steel or
nickel alloys for corrosion resistance in wells with high concentrations of H2S and/or
CO2. Packing and elastomeric materials for the valve are available for standard
service or special service to suit individual well conditions.
Features
Stainless steel or premium materials.
Three ply Monel bellows.
Teflon rings installed in each inside and outside
Bellows convolution prevents distortion and knife-edging which can lead to
rupture, while extending the life of the bellows.
Mechanical stop prevents bellows overstroke.
Viscous fluid shear dampening prevents bellows fatigue and stem-seat
pounding.
Replaceable floating Monel seat
Integral reverse flow check valve.
Injection Valve
20
The Wireline Retrievable Dummy Valve is a 1" / 1.5” OD valve that is used as a non-
equalizing isolation tool designed to be installed in a side pocket mandrels. The
Dummy valve consists of a body and nose. The valve is available in either stainless
steel or nickel alloys for corrosion resistance in wells with high concentrations of H2S
and/or CO2. Packing for the valve is available for standard service or special service
to suit individual well conditions. The simple design of the dummy valve allows for
easy replacement of the packing and for rapid low-cost repair of components. The
rugged, solid construction and quality materials provide for a long service life.
The BGI’s Latch is a wireline latch designed with a spring loaded latch ring to be used on top
mounted 1" OD gas lift valves, dummy valves, chemical injection valves and other
side pocket flow control devices which are not provided with integral latches.
This Latch is installed and removed from the mandrel pocket using standard wireline
methods. A minimum amount of force is required to install the latch. This is
particularly important in deviated wells where forceful downward jarring is not
possible.
The latch consists of a post, body, spring, ring, stop and brass shear pin. The latch
components are available in either stainless steel or nickel alloys for corrosion
resistance in wells with high concentrations of H2S and/or CO2.
Features
Simple design permits easy and rapid redress after service.
Installed and removed from side pocket mandrel using standard wireline tools
and methods.
A minimum amount of force is required to install latch in pocket. This feature
is particularly important in deviated wells where forceful downward jarring is not
possible.
Latch ring stop on latch body assures positive latching in mandrel pocket.
Dummy Valve
Valve Latch