U.S. patent application number 12/683489 was filed with the patent office on 2011-07-07 for retrofit wellbore fluid injection system.
Invention is credited to Henning Hansen.
Application Number | 20110162839 12/683489 |
Document ID | / |
Family ID | 43733309 |
Filed Date | 2011-07-07 |
United States Patent
Application |
20110162839 |
Kind Code |
A1 |
Hansen; Henning |
July 7, 2011 |
RETROFIT WELLBORE FLUID INJECTION SYSTEM
Abstract
A fluid injection system for a wellbore includes an adapter
configured to be retained in a safety valve landing nipple. The
landing nipple is disposed in a production tubing inserted in the
wellbore. The adapter includes a first sealed fluid passage between
a part of the tubing disposed above the adapter and a first fluid
injection line disposed in a part of the tubing below the adapter.
The adapter includes a second sealed fluid passage between a part
of the tubing below the adapter and a second fluid injection line
disposed inside the tubing above the adapter. The second fluid
injection line extends to a wellhead at an upper end of the
wellbore.
Inventors: |
Hansen; Henning; (Alicante,
ES) |
Family ID: |
43733309 |
Appl. No.: |
12/683489 |
Filed: |
January 7, 2010 |
Current U.S.
Class: |
166/268 ;
166/90.1 |
Current CPC
Class: |
E21B 34/105 20130101;
E21B 23/03 20130101; E21B 43/121 20130101; E21B 23/02 20130101;
E21B 17/18 20130101 |
Class at
Publication: |
166/268 ;
166/90.1 |
International
Class: |
E21B 43/16 20060101
E21B043/16 |
Claims
1. A fluid injection system for a wellbore, comprising: an adapter
configured to be retained in in a production tubing inserted in the
wellbore, the adapter including a first sealed fluid passage
between a part of the tubing disposed above the adapter and a first
fluid injection line disposed in a part of the tubing below the
adapter, the adapter including a second sealed fluid passage
between a part of the tubing below the adapter and a second fluid
injection line disposed inside the tubing above the adapter, the
second fluid injection line extending to a wellhead at an upper end
of the wellbore.
2. The adapter of claim 1 wherein the adapter is configured to be
retained in a safety valve landing nipple.
3. The fluid injection system of claim 1 further comprising at
least one gas lift valve disposed in the first fluid injection
line.
4. The fluid injection system of claim 1 further comprising a
safety valve disposed in the second sealed passage below the
adapter.
5. The fluid injection system of claim 4 further comprising an
hydraulic connector configured to establish hydraulic connection
between the safety valve and an hydraulic control line coupled to
the landing nipple.
6. The fluid injection system of claim 4 further comprising an
electrical connector configured to establish electrical connection
between the safety valve and an electrical control line coupled to
the landing nipple.
7. The fluid injection system of claim 1 further comprising an
electrical connector disposed on a lower end of the second fluid
injection line, the electrical connector configured to make
electrical connection between a first electrical cable disposed on
the second fluid injection line through the adapter to a second
electrical cable disposed on the first fluid injection line.
8. The system of claim 1 wherein the first sealed fluid passage
comprises at least one of an electrical cable, a fiber optical
cable and an hydraulic line extending from the wellhead to the
adapter, the adapter including internal connections between the at
least one of a electrical cable, fiber optic cable and hydraulic
line in the first sealed fluid passage and at least one of an
electrical cable, a fiber optic line and an hydraulic line
extending to a device disposed below the adapter.
9. The system of claim 8 wherein the at least one of an electrical
cable, a fiber optic line and an hydraulic line extending to a
device disposed below the adapter replaces the first fluid
injection line.
10. The fluid injection system of claim 8 further comprising at
least one sensor disposed on the first fluid injection line.
11. The fluid injection system of claim 1 further comprising an
hydraulic connector disposed on a lower end of the second fluid
injection line, the hydraulic connector configured to make
hydraulic connection between a first hydraulic line disposed on the
second fluid injection line through the adapter to a second
hydraulic line disposed on the first fluid injection line.
12. A method for installing a fluid injection system in a wellbore,
comprising: extending a first fluid injection tubing into a
production tubing into the wellbore; coupling an adapter to an
upper end of the first injection tubing, the adapter configured to
be retained in a safety valve landing nipple, the landing nipple
disposed in a production tubing inserted in the wellbore, the
adapter including a first sealed fluid passage between a part of
the production tubing disposed above the adapter and a first fluid
injection tubing, the adapter including a second sealed fluid
passage between a part of the production tubing below the adapter
and a second fluid injection tubing disposed inside the production
tubing above the adapter, the second fluid injection line extending
to a wellhead at an upper end of the wellbore; lowering the adapter
into the wellbore and engaging the adapter with the safety valve
landing nipple; extending a second fluid injection tubing into the
production tubing; and engaging a lower end of the second fluid
injection tubing with the adapter.
13. The method of claim 9 further comprising pumping fluid into the
second injection tubing.
14. The method of claim 10 wherein the fluid comprises gas.
15. The method of claim 11 further comprising opening a gas lift
valve disposed at a selected position along the first fluid
injection tubing.
16. The method of claim 9 further comprising extending an armored
electrical cable into the second injection tubing, through the
adapter and into the first injection tubing, engaging the armored
electrical cable to a device disposed in the first injection
tubing, and removing the device from the first injection tubing by
withdrawing the armored electrical cable.
17. The method of claim 9 wherein the extending the first fluid
injection tubing comprises extending a coiled tubing.
18. The method of claim 9 wherein the lowering the adapter
comprises extending an armored electrical cable.
19. The method of claim 9 wherein the extending the second fluid
injection tubing comprises extending a coiled tubing.
20. The method of claim 9 further comprising operating a safety
valve disposed in the second fluid passage.
21. The method of claim 17 wherein the operating the safety valve
comprises pumping hydraulic fluid into a control line coupled to
the landing nipple.
Description
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] Not applicable.
Statement regarding federally sponsored research or development
[0002] Not applicable.
BACKGROUND OF THE INVENTION
[0003] 1. Field of the Invention
[0004] The invention relates generally to the field of artificial
lift and safety valves for hydrocarbon producing wells. More
specifically, the invention relates to fluid injection devices that
can be retrofit into an existing subsurface safety valve landing
nipple.
[0005] 2. Background Art
[0006] Oil wells that produce for an extended period of time
typically will require artificial lift to be able to continue to
produce oil when natural reservoir pressure is no longer sufficient
to lift the oil to the Earth's surface. One such artificial lift
technique is to inject gas into the produced fluid, so-called "gas
lift", which assists the lifting of the produced fluids by lowering
their effective density. By lowering the effective density of the
produced fluid, less hydrostatic pressure is exerted against the
producing formation, thereby enabling pressure remaining in the
reservoir to move the produced fluid to the surface.
[0007] If a well equipped with a downhole safety valve (DHSV) is to
be equipped with a gas lift system, typically the well completion
system needs to be completely removed from the well and replaced
because it is generally impracticable to hang off a gas lift system
through the DHSV while maintaining the operation of the DHSV.
[0008] The foregoing may also apply to chemical injection into
certain wellbores, for example, chemicals used to dewater gas
producing wells. See, for example, U.S. Patent Application
Publication No. 2009/0266537 filed by Hansen et al.
[0009] There is a need for systems to enable retrofit fluid
injection into a completed wellbore without the need to remove an
existing completion system.
SUMMARY OF THE INVENTION
[0010] A fluid injection system for a wellbore according to one
aspect of the invention includes an adapter configured to be
retained in a safety valve landing nipple. The landing nipple is
disposed in a production tubing inserted in the wellbore. The
adapter includes a first sealed fluid passage between a part of the
tubing disposed above the adapter and a first fluid injection line
disposed in a part of the tubing below the adapter. The adapter
includes a second sealed fluid passage between a part of the tubing
below the adapter and a second fluid injection line disposed inside
the tubing above the adapter. The second fluid injection line
extends to a wellhead at an upper end of the wellbore.
[0011] A method for installing a gas injection system in a wellbore
according to another aspect of the invention includes extending a
first fluid injection tubing into a production tubing into the
wellbore. An adapter is coupled to an upper end of the first
injection tubing. The adapter is configured to be retained in a
safety valve landing nipple. The landing nipple is disposed in a
production tubing inserted in the wellbore. The adapter includes a
first sealed fluid passage between a part of the production tubing
disposed above the adapter and a first fluid injection tubing, and
a second sealed fluid passage between a part of the production
tubing below the adapter and a second fluid injection tubing
disposed inside the production tubing above the adapter. The second
fluid injection line extends to a wellhead at an upper end of the
wellbore. The adapter is lowered into the wellbore and engaged with
the safety valve landing nipple. A second fluid injection tubing is
extended into the production tubing and is a engaged with the
adapter.
[0012] Other aspects and advantages of the invention will be
apparent from the following description and the appended
claims.
BRIEF DESCRIPTION OF THE DRAWINGS
[0013] FIG. 1 illustrates a typical wellbore equipped with
production casing and tubing with a packer and a downhole safety
valve landing nipple.
[0014] FIG. 2 illustrates a insert retrofit fluid injection adapter
system installed in a typical well completion as illustrated in
FIG. 1, where the fluid injection adapter system is landed in the
existing safety valve or alternatively in a special nipple profile
for a standard wireline safety valve. Also illustrated is a jointed
or coiled tubing string suspended below the fluid injection adapter
system, where a gas lift valve is incorporated in the lower end of
a fluid injection tubing string.
[0015] FIG. 2A shows the adapter system of FIG. 2 disposed below a
safety valve in the tubing which either has had the valve insert
removed or the safety valve has been locked open.
[0016] FIG. 3 illustrates the fluid injection adapter system in
more detail.
[0017] FIGS. 3A and 3B show cross sections of the fluid injection
adapter system of FIG. 3.
[0018] FIG. 4 shows the system of FIG. 3, but includes fluid flow
paths between a stinger system suspended from the wellhead and a
tubing suspended below the valve adapter system. Also shown is how
wellbore production fluids are routed via a standard wireline valve
connected to the lower side of the fluid injection valve adapter to
the production tubing area outside the stinger system. Wireline
replacement of the fluid injection valve in the lower end of the
tubing below the fluid injection valve adapter system can be
possible where the downward facing arrows are placed.
[0019] FIGS. 4A and 4B show cross sections of the adapter system of
FIG. 4.
[0020] FIG. 5 illustrates how an electrical ring type coupler can
be incorporated in the stinger and fluid injection valve adapter,
where the ring type coupler enables communication with a sensor
below the adapter for monitoring of pressure, temperature, etc.
[0021] FIGS. 5A and 5B show cross sections of the example system of
FIG. 5 at similar longitudinal positions as the cross sections of
FIGS. 4A and 4B.
[0022] FIG. 6 shows the system of FIG. 5 with the additional option
of introducing one or more additional electrical couplers as well
as one or several hydraulic couplers into the stinger and the fluid
injection valve adapter system.
[0023] FIGS. 6A and 6B show cross sections of the system of FIG. 6
at similar longitudinal positions as the cross sections of FIGS. 4A
and 4B.
[0024] FIGS. 7A, 7B and 7C illustrate one technique for installing
a system according to the invention in a wellbore.
[0025] FIG. 8 shows an example of a wireline lock used in the
example of FIG. 2A
DETAILED DESCRIPTION
[0026] FIG. 1 illustrates part of a typical wellbore completed with
a production casing (1) and a production tubing (2). The production
tubing (2) is disposed inside the casing (1) and an annular space
between the casing (1) and the production tubing (2) may be sealed
using an annular seal such as a packer (25). The production tubing
(2) may be hydraulically closed from below by operation of a
downhole safety valve (not shown). The downhole safety valve (not
shown) in the present example is a retrievable type and may be
conveyed through the tubing (2) by wireline, slickline, coiled
tubing or similar conveyance into a landing nipple (4) that is
assembled in the production tubing (2) at the time the wellbore is
completed. The safety valve (not shown) is typically operated by an
actuator (not shown) which can be connected to a control line (5),
for example, a, hydraulic line or an electric power cable extending
from a wellhead (see FIGS. 7A, 7B, 7C) to the landing nipple (4).
One example of a wireline deployable and retrievable downhole
safety valve is described in U.S. Pat. No. 3,971,438 issued to
Crowe. The safety valve may also be incorporated as part of the
production tubing, as typically referred to as a tubing retrievable
downhole safety valve, where the production tubing will need to be
retrieved to surface to repair or replace the safety valve. Such
tubing mounted valves typically incorporates the ability to be
locked open by e.g. a wireline intervention, where after a wireline
retrievable valve can be mounted into a nipple profile. This type
of safety valve is are operated from the wellhead (FIGS. 7A. 7B.
7C) by the control line(s) (5) used to operate the tubing mounted
valve.
[0027] The illustration in FIG. 1 shows the wellbore with the
safety valve removed from the landing nipple (4), or, alternatively
the tubing mounted safety valve locked open, so that a fluid
injection valve adapter system according to the various aspects of
the invention may be inserted into the landing nipple (4) without
the need to remove the tubing (2) from the wellbore. When the
safety valve (not shown) is removed from the landing nipple (4), or
the tubing mounted safety valve is locked open by well
intervention, the control line (5) remains in place and may be used
to operate parts of the fluid injection adapter system as will be
further explained below.
[0028] FIG. 2 shows an example fluid injection valve adapter system
(6) landed into the safety valve landing nipple (4). The fluid
injection valve adapter system (6) includes devices (explained
below) to enable hydraulic connection of a fluid injection line
(10) that extends from the wellhead (see FIGS. 7A, 7B, 7C) to a
fluid injection tubing (8) disposed below the adapter (6). The
adapter (6) also enables hydraulic connection of the casing (1) and
tubing (2) below the adapter (6) to the portion of the tubing (2)
above the adapter (6) so that produced fluid from formations
generally below the bottom of the tubing (2) can move to the
surface.
[0029] The fluid injection valve adapter (6) may include a wireline
deployed safety valve (7) of any type known in the art, for
example, the one described in the Crowe '438 patent referenced
above. The fluid injection valve adapter (6) may include internal
connections (explained below) to enable operation of the safety
valve (7) using the existing control line (5) that is coupled to
the landing nipple (4). The safety valve (7) may be mounted
alongside a fluid injection pipe string (8), which may be a jointed
pipe string or a continuous length of tubing that may be deployed
by a coiled tubing deployment unit, as will be explained below with
reference to FIGS. 7A, 7B and 7C. Also, an additional safety valve
(7A) may be mounted on the fluid injection pipe string (8).
[0030] The fluid injection string (8) is used to transport fluid,
for example, gas, down to a gas lift valve (9) mounted in the lower
end of the fluid injection string (8). A plurality of individual
gas lift valves can be installed at predetermined positions along
the fluid injection string (8) if, for example, so-called side
pocket mandrels are used. Non-limiting examples of gas lift valves
and systems including side pocket mandrels are described in U.S.
Pat. No. 5,066,198 issued to Decker.
[0031] The fluid injection valve adapter system (6) may deployed
into the tubing (2), and is then landed in the safety valve landing
nipple (4). The foregoing deployment operation can be performed
using an armored electrical cable ("wireline"), a wellbore
intervention rod, coiled tubing or any other conveyance device
known in the art. After the fluid injection adapter system (6) is
landed in the landing nipple (4), the fluid injection line (10) can
be deployed through the wellhead until the fluid injection line
(10) lands into the fluid injection valve adapter system (6). A
hang-off system (not shown) can be used in the wellhead (not shown)
to enable gas injection, chemical injection, electrical coupling to
downhole tools, etc. through the fluid injection line (10).
[0032] It should also be noted that a safety valve can be mounted
between the fluid injection valve adapter (6) and the fluid
injection string (8). Alternatively such a safety valve can be
mounted onto the tubing string extending below the wireline
deployed safety valve (7) to control wellbore fluid production.
Such a safety valve can be connected to the same hydraulic supply
as the production safety valve (7), either via the control line (5)
mounted externally on the tubing (2) or via a control line
incorporated from surface onto the fluid injection line (10)
retrofitted into the existing tubing (2). Such a control line can
be strapped externally on the fluid injection line (10), using
clamping devices commonly known to the industry. Examples of such
control lines will be shown in and explained with reference to
FIGS. 5 and 6. An example of an adapter system set in the wellbore
below the existing safety valve is shown in FIG. 2A. In such
examples, the safety valve (7) would typically be operated by
control lines (See FIG. 6) associated with the fluid injection line
(10).
[0033] FIG. 3 shows a cut away view of the fluid injection valve
adapter system (6) mounted in the safety valve landing nipple (4).
The fluid injection valve adapter system (6) may include a mandrel
(6A) having internal fluid passages as will be further explained.
An industry standard wireline lock (11), as for example the DB-6
series type sold by Schlumberger Technology Corporation, Sugar
Land, Tex. 77479, USA, as illustrated in FIG. 8, can be used to
secure the mandrel (6A) in place in the landing nipple (4). Below
the wireline lock (11) two sets of seal systems (12a and 12b) are
used to seal the ends of the mandrel (6A) inside the landing nipple
(4) so that hydraulic fluid can be routed from the control line (5)
to the safety valve (7).
[0034] A stinger system incorporating a seal stem (13), and if
required, a latching anchor system (not shown separately), can be
coupled to a telescoping travel joint (14) coupled between the
fluid injection line (10) and the seal stem (13). The telescoping
travel joint (14) is used to take up any depth misalignment and
temperature expansions and contractions of the fluid injection line
(10) above the fluid injection adapter system (6). The seal stem
(13) seals the fluid injection line in a passage in the adapter
system (6) so that fluid (15) pumped through the injection line
(10) is constrained to flow into the fluid injection string (8)
from the fluid injection line (10). Fluid (15), for example gas,
can be injected through the fluid injection line (10) as shown by
downward arrows and move into the fluid injection string (8), while
fluid production to the surface can simultaneously take place
through the existing production tubing (2) as shown by upward
arrows. The fluid injection string (8) can also be used as an
injection tubing for chemical treatments, for example in gas well
dewatering using a foaming agent.
[0035] FIG. 3A shows a cross section of a lower part fluid
injection adapter system (6 in FIG. 3). An opening (22A) for the
fluid injection string (8 in FIG. 3) and an opening (22B) for the
safety valve (7 in FIG. 3) in the mandrel (6A in FIG. 3) are shown.
FIG. 3B shows a cross section of an upper part of the adapter
system (6 in FIG. 3). The mandrel therein may include an opening
20A for sealing engagement with the seal stem (13 in FIG. 3) and
openings 20B for produced fluid to move into the annular space
between the fluid injection line (10 in FIG. 3) and the tubing (2
in FIG. 3).
[0036] In some cases the existing safety valve landing nipple (4)
may not have sufficient weight supporting capacity to support the
hanging weight of the fluid injection valve adapter system (6). In
such cases, a slip-type gripping system (not shown) or similar
device can be incorporated in the fluid injection adapter system
(6) to assist in supporting the weight thereof.
[0037] FIG. 4 illustrates in more detail how fluid (15) pumped down
the injection line (10) and produced reservoir fluids (16) from
below the adapter system (6) can be routed through the fluid
injection valve adapter system (6). In the present example, an
optional backpressure valve (17) can be included in the fluid
injection string (8). The backpressure valve (17) is configured to
close if gas or fluids are returned up the fluid injection string
(8) as a result of higher pressure at the lower end of the fluid
injection string than the pressure of the fluid (15) being injected
through the fluid injection line (10). The backpressure valve (17)
can be a mechanical type check valve type, or it can be
hydraulically or electrically operated using devices explained
below with reference to FIGS. 5 and 6. This valve (17) can also be
placed further down on the fluid injection line (8) to a location
below safety valve (7) in cases where size constrains requires
such.
[0038] FIGS. 4A and 4B show, respectively, the same cross sections
22, 20, explained above with reference to FIGS. 3A and 3B.
[0039] FIG. 5 shows one or more electrical couplers (18) can be
incorporated in the stinger system and the fluid injection valve
adapter (6). The fluid injection line (10) may include an hydraulic
line (19) to enable hydraulically flushing the coupler (18) by
pumping dielectric fluid through the hydraulic line (19).
Electrical connection to the surface may be made using with one or
more upper electric cables (20) attached to the exterior of the
fluid injection line (10). Flushing would typically be performed
prior to and when landing the stinger system into the fluid
injection adapter system (6). The electrical couplers (18) enable
electrical connection from the upper cable(s) (20) to one or more
corresponding lower electrical cables (26) attached to the exterior
of the fluid injection string (8). The upper electrical cables (20)
and lower electrical cables (26) can provide signal connection
between sensors, one example of which is shown at (28), for
example, pressure or temperature sensors, and the surface. The
upper electrical cables (20) and lower electrical cables (26) may
also be used to provide electrical power from the surface to any
electrically operated device (not shown) disposed in the lower part
of the wellbore. The foregoing features enable the introduction and
operation of any electrically operated downhole sensors, tools,
etc., which can be mounted within or externally to the fluid
injection string (8) and disposed at the required wellbore depth.
Such sensors or tools can be operated simultaneously to performing
fluid injection. Alternatively, the fluid injection string (8) can
be substituted entirely by the lower electrical cables (26) used to
operate sensors, motors, valves, etc., at any required depth within
the wellbore. It should be understood that the upper electrical
cable (20) and the lower electrical cable can be substituted by or
supplemented with fiber optic cables or lines and hydraulic lines
to establish power and communication with any devices in the
wellbore below the adapter (6).
[0040] FIGS. 5A and 5B show, respectively, cross sections 22D, 22C
the lower and upper parts of the adapter system. The cross sections
22D, 22C in the present example include openings for the upper
electrical cables (20 in FIG. 5) and the lower electrical cables
(26 in FIG. 5).
[0041] FIG. 6 illustrates one or more hydraulic couplers (21) in
the seal stem (13) and the mandrel (6A in FIG. 3) in addition to
the electrical couplers (18) explained above with reference to FIG.
5. In the present example, it is possible to perform wireline
intervention through the fluid injection line (10), fluid injection
adapter system (6) and the fluid injection string (8), so that, for
example, a gas lift valve (9) or similar device can be replaced
without having to retrieve the entire valve adapter system (6) to
the surface. Such valve or device replacement may be required due
to valve failure, requirements to change the gas injection valve
(9) to a valve with different operating pressure, etc. An example
wireline deployment unit is shown in FIG. 7B, and such unit may be
used for the foregoing intervention.
[0042] Also, several gas lift valves, chemical injection valves,
etc., can be placed at various places along the fluid injection
string (8) suspended below the valve adapter system (6) as
explained above with reference to FIG. 2.
[0043] FIGS. 6A and 6B, show, respectively, cross sections 22F, 22E
of the lower and upper parts of the example fluid injection adapter
system using hydraulic and electrical lines as explained with
reference to FIG. 6.
[0044] In a particular implementation of the adapter system shown
in FIG. 6, because the seal stem 13 includes both electrical
contacts (18) and fluid pressure seals (21), it is possible to
configure the upper fluid injection line (11) as an "umbilical"
electrical and/or hydraulic cable. In such examples, the fluid
injection line (10) may be supplemented or substituted by
electrical cables, fiber optic lines and/or hydraulic control
lines. Using the seal assemblies and contacts, for example as shown
in FIGS. 6 at 13, 18, and 21, respectively, electrical, optical and
or hydraulic signals may be communicated from the surface (e.g.,
wellhead 30 in FIGS. 7A, 7B, 7C) to instruments and/or sensors that
may be deployed below the adapter (6). In one example, the lower
fluid injection string (8) may be substituted by a second umbilical
cable, including electrical cable, fiber optic lines and/or
hydraulic lines. Such lines and cables can establish control and
communication between sensors or other devices (pumps, etc.)
disposed below the adapter.
[0045] A system according to the invention can also provide for
placing a safety valve deeper in the wellbore than the existing
safety valve landing nipple (4 in FIG. 2). Such a deeper location
can be required due to faulty safety valve landing nipple (4 in
FIG. 2), a need to mount a insert valve system closer to the
downhole packer (25 in FIG. 1), etc. This deeper location can be a
nipple profile, or within the tubing string where a slips
arrangement would be required to lock the system in place. Such a
safety valve may be operated from the surface by hydraulic or
electric power via one or several cables and/or control line(s)
explained with reference to FIGS. 5 and 6.
[0046] FIGS. 7A, 7B and 7C show one technique for installing a
system as explained above in a wellbore. FIG. 7A shows a coiled
tubing deployment unit (32) of any type known in the art disposed
proximate the wellhead (30). The fluid injection string (8) may be
coiled tubing, as explained with reference to FIG. 2. The fluid
injection string (8) is inserted to a selected depth in the
wellbore through the wellhead (30), the depth being selected so
that the upper end of the fluid injection string (8) will be at a
depth such that the adapter system (6 in FIG. 2) can be seated in
the landing nipple (4 in FIG. 1). Once the selected depth has been
reached, the fluid injection string (8) can be hung in the wellhead
30, with the upper end of the injection string (8) disposed above
the wellhead (30) to enable connection of the adapter system (6 in
FIG. 2).
[0047] In FIG. 7B, a wireline deployment unit (36) of any type
known in the art, which extends and retracted armored electrical
cable (38) and a supporting mast unit (34) may be deployed
proximate the wellhead (30). The adapter system (6) may be coupled
to the upper end of the fluid injection string (8). The end of the
cable (38) may be connected to the adapter system (6). After such
connection, the adapter system (6) is lowered by the cable (38)
into the wellbore until the adapter system (6) seats in the landing
nipple, as explained with reference to FIG. 2.
[0048] In FIG. 7C, the coiled tubing deployment unit (32) may be
used to extend the fluid injection line into the wellbore until the
stinger system (13 in FIG. 3) seats in the adapter system (6 in
FIG. 2) as explained above with reference to FIG. 3. In examples
using hydraulic lines and/or electrical cables as explained with
reference to FIGS. 5 and 6, surface connections to such lines
and/or cables may be made to suitable devices (not shown)
externally to the wellhead 30 after the fluid injection line 10 is
fully extended into the wellbore.
[0049] While the invention has been described with respect to a
limited number of embodiments, those skilled in the art, having
benefit of this disclosure, will appreciate that other embodiments
can be devised which do not depart from the scope of the invention
as disclosed herein. Accordingly, the scope of the invention should
be limited only by the attached claims.
* * * * *