U.S. patent number 3,653,435 [Application Number 05/064,519] was granted by the patent office on 1972-04-04 for multi-string tubingless completion technique.
This patent grant is currently assigned to Esso Production Research Company. Invention is credited to Joseph A. Burkhardt, Thomas W. Childers, Dewitt L. McLallen, Jr., Carl E. Reistle, III, Carroll A. Woolley.
United States Patent |
3,653,435 |
Reistle, III , et
al. |
April 4, 1972 |
MULTI-STRING TUBINGLESS COMPLETION TECHNIQUE
Abstract
Method and apparatus for completing multi-string tubingless
underwater wells with through flowline (TFL) pumpdown tool
servicing capability. A subsea borehole is drilled through the
productive oil and/or gas formations. At least two parallel small
diameter casing strings are run into the borehole guided by a riser
assembly. These casing strings have a common hanger at their upper
ends and are connected together at various levels with a plurality
of gas-lift crossover mandrels and at least two (upper and lower)
circulation crossover mandrels for tool circulation. Then a Xmas
tree is lowered on a disconnectable running pipe to a wellhead
guided by guidelines. The Xmas tree has at least two parallel small
diameter casing strings extending from the lower end thereof. These
upper casing strings have a common connector on their lower ends
for connection to the hanger. Each upper casing string fluidly
communicates with a lower casing string through the connector and
hanger. A tensioner located in the Xmas tree applies tension to
both the upper and lower sections of casing strings and properly
spaces out the upper ends of the upper sections of casing strings
in the Xmas tree. The upper ends of the casing string sections in
the Xmas tree are connected to a production manifold. Suitable
control fluid conduits are lowered with the Xmas tree for operation
of the tensioner and for operation of safety valves located in each
of the upper sections of casing strings. The lower circulation
crossover port between two of the casing strings is then opened for
perforating operations. A perforator gun is landed in a landing
nipple adjacent a formation and is reciprocated until it rotates to
the proper direction to avoid perforating the other pipe string in
the borehole and then is fired. After each of the formations has
been perforated, production of the formation may be maintained by
natural formation energy. Various well servicing operations may be
carried out using pump-down tools and techniques. A producing
formation or zone may be blocked off using a pump-down patch tool
and the well fluids may be artificially lifted by positioning
pump-down gas-lift valves in one of the casing strings.
Inventors: |
Reistle, III; Carl E. (Houston,
TX), Childers; Thomas W. (Woodland Hills, CA), Burkhardt;
Joseph A. (Chatsworth, CA), McLallen, Jr.; Dewitt L.
(Corpus Christi, TX), Woolley; Carroll A. (Chatsworth,
CA) |
Assignee: |
Esso Production Research
Company (N/A)
|
Family
ID: |
22056534 |
Appl.
No.: |
05/064,519 |
Filed: |
August 14, 1970 |
Current U.S.
Class: |
166/366; 166/313;
166/348; 166/344 |
Current CPC
Class: |
E21B
43/14 (20130101); E21B 33/035 (20130101) |
Current International
Class: |
E21B
33/035 (20060101); E21B 33/03 (20060101); E21B
43/14 (20060101); E21B 43/00 (20060101); E21b
043/00 () |
Field of
Search: |
;166/.5,224,255,315,285,189,89,313 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Leppink; James A.
Claims
Having fully described our invention, including the objects and
advantages thereof, and illustrated its use, we claim:
1. A method for completing a multi-string tubingless well in which
a borehole has been drilled through a productive hydrocarbon
formation and provided with a surface casing and a wellhead
comprising the steps of:
1. running the lower sections of at least two parallel casing
strings into said surface casing and said borehole on at least two
parallel running pipes releasably attached to said lower
sections;
2. cementing said lower sections in said borehole, said lower
sections being connected together at a plurality of levels by
crossover mandrels, each of which includes a crossover port fluidly
communicating said lower sections and a sleeve valve shiftable to
open or close off said crossover port, said crossover ports
remaining closed during said cementing step;
3. connecting said lower sections to said surface casing a selected
distance below the wellhead by means of a hanger attached to the
upper ends of said lower sections;
4. opening one of said crossover ports;
5. detaching and removing said parallel running pipes;
6. lowering a Xmas tree assembly having vertical bores extending
therethrough and curved bores branching from said vertical bores to
said wellhead;
7. connecting at least two parallel upper sections of said casing
strings which extend from the vertical bores of said Xmas tree
assembly to said hanger by means of a connector positioned on the
lower ends of said upper sections, the upper sections communicating
with the lower sections through the hanger and connector when said
Xmas tree assembly is positioned on said wellhead;
8. connecting the curved bores of said Xmas tree assembly to
production and servicing facilities;
9. pumping a perforator down one of said casing strings to adjacent
said formation with the fluid circulation path being down said one
casing string, through said one crossover port and up said other
casing string;
10. orienting said perforator to fire away from said other casing
strings; and
11. firing said perforator to perforate said formation.
2. A method as recited in claim 1 in which said borehole has been
drilled through at least two productive hydrocarbon formations and
including perforating each of said formations sequentially
beginning with the lowest level formation.
3. A method as recited in claim 1 including hydraulically actuating
said hanger to connect said lower sections to said surface
casing.
4. A method as recited in claim 3 including hydraulically detaching
said parallel running pipes from said hanger.
5. A method as recited in claim 4 including hydraulically
connecting said upper sections of said casing strings to said
hanger.
6. A method as recited in claim 5 in which said borehole is subsea
and including arranging hydraulically operated safety valves in the
lower ends of said lower sections to close off flow of fluids
through said lower sections.
7. A method as recited in claim 6 including placing said upper and
lower sections of said casing strings in tension and spacing out
the upper ends of said upper sections to accommodate said upper
sections in the bores of said Xmas tree assembly following
connection of said upper sections to said hanger.
8. A method as recited in claim 6 and including well servicing
operations in which gas-lift mandrels having gas-lift mandrel
sleeves therein are located adjacent crossover ports and including
pumping a train of gas-lift valves and a gas-lift mandrel sleeve
shifter into one of said casing strings to below said gas-lift
mandrels with the fluid circulation path being down said one casing
string, through said one crossover port and up said other casing
string; and
reverse circulating pump fluid to move said train of valves
upwardly through said gas-lift mandrels to shift said gas-lift
mandrel sleeves open as said sleeve shifter passes each gas-lift
mandrel sleeve and depositing a gas-lift valve in each gas-lift
landing nipple.
9. A method as recited in claim 6 in conjunction with well
servicing operations including pumping a locomotive tool string
comprising a patch tool, and a running tool for said patch tool
down one of said casing strings with the fluid circulation path
being down said one casing string through said one crossover port
and up said other casing string;
landing said locomotive tool in a landing nipple in said one casing
string; and
blanking off a perforated interval with said patch tool.
10. A method for completing and servicing submerged multi-string
tubingless TFL wells in which subsea boreholes have been drilled
through subteranean formations, each of said boreholes being
provided with surface casing and a wellhead comprising the steps
of:
1. positioning an underwater platform having a plurality of well
bays on water bottom, one well bay being associated with each of
said cased boreholes and each well bay having a guide system for
guiding equipment into and from said borehole, said platform being
also provided with a manifold for connecting each well with
production and servicing facilities; and
2. With respect to each well conducting the following steps:
a. running the lower sections of at least two parallel casing
strings into said surface casing and said borehole on at least two
parallel running pipes releasably attached to said lower
sections;
b. cementing said lower sections in said borehole, said lower
sections being connected together at a plurality of levels by
crossover mandrels, each of which includes a crossover port fluidly
communicating said lower sections and a sleeve valve shiftable to
open or close off said crossover port, said crossover ports
remaining closed during said cementing step;
c. connecting said lower sections to said surface casing a selected
distance below the wellhead by means of a hanger attached to the
upper ends of said lower sections;
d. opening one of said crossover ports;
e. detaching and removing said parallel running pipes;
f. lowering a Xmas tree assembly having vertical bores extending
therethrough and curved bores branching from said vertical bores to
said wellhead;
g. connecting at least two parallel upper sections of said casing
strings which extend from the vertical bores of said Xmas tree
assembly to said hanger by means of a connector positioned on the
lower ends of said upper sections, the upper sections communicating
with the lower sections through the hanger and connector when said
Xmas tree assembly is positioned on said wellhead;
h. connecting the curved bores of said Xmas tree assembly to
production and servicing facilities;
i. pumping a perforator down one of said casing strings to adjacent
said formation with the fluid circulation path being down said one
casing string, through said one crossover port and up said other
casing string;
j. orienting said perforator to fire away from said other casing
strings; and
k. firing said perforator to perforate said formation.
11. Apparatus for use in completing a multi-string tubingless well
and for conducting well servicing operations using pump-down tools
and techniques comprising:
a surface casing cemented in said well;
the lower sections of at least two casing strings cemented in said
well and connected to said surface casing at the upper ends
thereof;
said lower sections being provided with a plurality of crossover
mandrels for use in gas-lift operations and fluid circulation
crossover mandrels to establish fluid circulation paths for
pump-down tool operations, each crossover mandrel including a port
fluidly communicating said lower sections and a sleeve shiftable to
open or close off said crossover port;
a plurality of landing nipples arranged in each lower section
between said uppermost and lowermost circulation crossover
ports;
at least two upper sections of said casing strings detachably
connected to said lower sections of said casing strings; and
a Xmas tree connected to said upper sections.
12. Apparatus as recited in claim 11 including manifold pipes
arranged adjacent and connected to said Xmas tree for carrying
fluids between said well and producing and servicing
facilities.
13. Apparatus as recited in claim 12 in which said Xmas tree is
provided with vertical bores therethrough and branched bores
curving from said vertical bores, said branched bores being
connected to said manifold pipes.
14. Apparatus as recited in claim 13 including hydraulically
actuated means connecting said lower sections to said surface
casing.
15. Apparatus as recited in claim 14 including hydraulically
actuated means for attaching and detaching said upper sections to
said lower sections.
16. Apparatus as recited in claim 15 including a plurality of said
cased submerged wells; and
an underwater platform having a plurality of well bays positioned
on water bottom, one well bay having a guide system for moving
equipment into and from said well being associated with each of
said cased wells.
17. Apparatus as recited in claim 16 including means for applying
tension to said upper and lower sections to position said upper
sections properly in said Xmas tree.
18. Apparatus as recited in claim 17 in which said means for
applying tension comprises hydraulically operated pistons located
in said Xmas tree.
Description
BACKGROUND OF THE INVENTION
Field of the Invention
The present invention relates to a method for completing and
servicing a multiple-string tubingless well which has through
flowline (TFL) pump-down tool servicing capability as well as
conventional vertical reentry servicing capability. This type well
is referred to herein as tubingless TFL. Such well completion and
servicing techniques have application, all or in part, to
underwater wells, highly deviated offshore wells drilled from
platforms or piers, deviated wells drilled from urban well sites,
or deviated wells drilled from land to adjacent underwater
reservoir targets.
When completing and servicing wells with underwater wellheads or
where the wellbore is highly deviated, hydraulic (TFL) well
servicing techniques are applicable. The use of TFL tool pump-down
completion and servicing techniques permits relatively inexpensive
well work to be conducted from remote locations. For example, if an
underwater well is drilled and the well is tied by pipelines into a
shore facility, a platform, or a floating vessel some distance away
or immediately above the well, the well may be completed and
serviced by pumping special completion and workover tools down the
pipelines and into the well. By providing multiple well pipe
(casing) strings in the wellbore with crossover ports between the
casing strings and a pipeline flow path (TFL lines) back to the
service facility for each casing string, the TFL pump-down tools
may be circulated to and from the wellbore. By utilizing a manifold
near the wellheads, clustered underwater wells may share common TFL
lines. Hydraulic completion and servicing techniques have
application in highly deviated wells drilled from land where
vertical (pipe or wireline) completion and servicing techniques are
deemed impossible because severe dog-legs in the wellbore prevent
running or retrieving the tools by conventional vertical entry
methods.
The use of multiple (preferably dual) parallel casing strings in
the borehole effects a considerable saving over the cost of
purchasing and handling the larger diameter outside casing string
usually run in a conventional, tubing-casing, completion. The use
of such relatively small diameter pipes cemented in the borehole
and elimination of the use of inside tubing is commonly referred to
as a tubingless well technique.
The problem, therefore, which the present invention overcomes is
that of providing a method, and apparatus for conducting the
method, for completing wells which permits less expensive
completion and servicing of underwater, platform, or land wells
than is possible with conventional well operations and permits
completion and servicing of highly deviated wells where
conventional techniques are deemed impossible due to dog-leg
severity.
SUMMARY OF THE INVENTION
Method and apparatus for completing a submerged multi-string
tubingless TFL well in which an underwater platform or template
having a plurality of well bays is positioned on water bottom. Each
well day is provided with a pipe manifold and a guide system. After
a borehole has been drilled through a well bay and cased, the lower
sections of two parallel casing strings are run into the borehole
on two parallel running pipes which are releasably attached to a
hanger which is connected to the upper ends of said lower sections.
The lower sections are suspended in the cased borehole by the
hanger and cemented in the borehole. The lower sections are
connected together at a plurality of levels by crossover mandrels
each of which includes a crossover port fluidly communicating the
lower sections and a sleeve valve shiftable to open or close off
the crossover port. The parallel running pipes are removed and a
Xmas tree assembly is lowered and landed on a wellhead mounted on
top of the borehole. The Xmas tree assembly suspends the upper
sections of the parallel casing strings and a connector positioned
on the lower end of the upper sections for connecting the upper
sections to the hanger. When the Xmas tree assembly has been landed
and the connector is connected to the hanger, the upper sections of
the casing strings communicate with the lower sections of the
casing strings through the hanger and connector. The hanger
contains slips which are hydraulically actuated. The connector is
also hydraulically operated to connect it to and disconnect it from
the hanger. The upper ends of the upper sections of the casing
strings connect into vertical bores formed in the Xmas tree
assembly. These bores extend vertically through the Xmas tree and
other curved bores branch from the vertical bores and connect with
the manifold piping. A tensioner may be provided in the Xmas tree
assembly to place the upper and lower sections of the parallel
casing strings in tension and space out the upper ends of the upper
sections to accommodate their connection to the bores in the Xmas
tree. The tensioner is hydraulically operated. Safety valves are
provided in the lower portions of the upper sections. The vertical
bores of the Xmas tree above the branched bores are normally closed
by diverter plugs. A perforating gun is pumped down one casing
string and rotated and fired when landed in a landing nipple
adjacent the formation to be perforated and directed away from the
adjacent casing string. Servicing of the well including closing off
particular formations and gas-lifting well fluids may be carried
out using TFL pump-down tools and techniques. The vertical bores in
the Xmas tree permit, when desired, vertical reentry to the
well.
BRIEF DESCRIPTION OF THE DRAWINGS
FIGS. 1, 2, and 9 to 14 inclusive illustrate schematically the
steps involved in completing a two pipe string tubingless TFL well;
and
FIGS. 3 to 8 inclusive illustrate portions of the apparatus used in
the completion and servicing method in more detail.
DESCRIPTION OF THE PREFERRED EMBODIMENTS
There is shown in FIG. 1 an underwater platform or template 2
positioned on water bottom 3. The platform is provided with a
plurality of well bays 4 with each of which is associated a guide
tube 5, a guide system 6 and a manifold 7. Guide system 6 includes
guide post 6A and cables 6B extending from the guide post to the
water surface. The platform is installed by lowering it from barges
on cables. Each manifold arrangement is also provided with an
antipollution spill pan which is described in detail in U.S. Pat.
application Ser. No. 174, titled "Underwater Pollution Control" by
Thomas W. Childers. After the platform has been positioned a
drilling vessel is moved in and positioned over a selected well bay
4. A drill pipe 8 is run with a drill bit and a hole opener or
reamer through guide tube 5 guided by the guide system 6 and a
conductor casing hole is drilled to a depth of about 400 to 500
feet below the mud line or water bottom 3. During such drilling,
returns and cuttings accumulate under the submerged platform and
not on the deck of the underwater platform 2 since the conductor
guide tube 5 does not contact water bottom 3. Drill pipe 8 along
with the drill bit and reamer are then pulled from the conductor
hole and the water.
A conductor casing 11 having a wellhead mounted on its upper end is
then lowered on drill pipe 8 into the conductor borehole and
cemented in place by pumping cement down drill pipe 8 from the
water surface and into the borehole. Drill pipe 8 is then
disconnected and removed.
A marine riser assembly 13 having a releasable connector 14 on its
lower end and having a guide frame 10 connected to it is lowered on
guide lines 6B using guide frame 10 until connector 14 engages
wellhead 12. Riser assembly 13 includes a drilling spool 15, a
blowout preventer (BOP) stack 16, a flexible joint 17 and a slip
joint 18. The riser assembly 13 is provided with a releasable
connector 19 positioned above BOP stack 16. Drilling spool 15 is of
sufficient length to permit positioning of the BOP stack above
manifold 7 arranged on the deck of platform 2. Drill pipe 8 with a
drill bit arranged on the lower end thereof is then run into
conductor casing 11 using the riser assembly as a guide. The
surface hole is drilled with returns being taken up the annulus
between the conductor casing 11 and the interior wall of riser
assembly 13. After the surface casing hole has been drilled to a
desired depth, drill string 8 and drill bit 16 are removed.
A surface casing 20 is positioned in the borehole. The upper end of
surface casing 20 is connected by a connector to a running string
which is of the same size as the casing. Surface casing 20 is
guided into wellhead 12 and conductor casing 11 by riser assembly
13 and the upper end is landed in wellhead 12. Surface casing 20 is
cemented in by pumping cement down the running string and connector
and surface casing 20 and up the annulus surrounding surface casing
20. The running string and surface casing 20 are reciprocated
during the cementing operation and returns are taken at the deck of
platform 2 at the wellhead. The running string is then disconnected
from surface casing 20 and removed.
As shown in FIG. 1, drill pipe 8 with a drill bit 9 attached on the
lower end thereof is run into surface casing 20 guided by riser
assembly 13 and the borehole is drilled to total depth. The drill
pipe and drill bit are then removed. The borehole may then be
logged and/or other evaluation tools may be run.
As shown in FIG. 2, the borehole penetrates two formations A and B.
The lower sections 21 and 22 of two parallel small diameter casing
strings are arranged in the borehole. The upper ends of these lower
sections are connected together by a common hanger 33 to which is
connected releasably a running tool 34. These members are shown in
greater detail in FIGS. 3 to 8. Running tool 34 is connected to the
lower ends of running parallel pipe strings 35 and 36. Pipe 35 is
in communication with pipe 21 through running tool 34 and hanger 33
and pipe 36 is in communication with casing 22 through running tool
34 and hanger 33. Pipe 21 is provided with a sleeve valve 23, which
contains a crossover to pipe 22, and landing nipples 24, 25, 26,
and 27, which are placed so as to position them above and below
each of the formations A and B. The lower end of casing 21 is
provided with a cementing shoe 28. Casing 22 is provided with
sleeve valves 29, 30, and 31 and is closed off at its lower end by
a bull plug 32. Sleeve valves 29 and 30 are positioned so as to be
a substantial distance above formation A and also above sleeve
valve 23. Sections 21 and 22 are run into the borehole on running
strings 35 and 36 guided by riser assembly 13. In the running-in
position, all of the crossovers between the two casings are
closed.
Hanger 33 is positioned at least 100 feet below the mud line or
water bottom. While the dual casings 21 and 22 and dual pipes 35
and 36 are reciprocated, cement is pumped down running string 35
through running tool 34 and hanger 33 and through casing 21 and up
around casings 21 and 22 until the top of the cement is at the
desired height in the wellbore. After the wiper plug (not shown)
has bumped bottom in shoe 28, hanger 33 is actuated to suspend
casings 21 and 22 in surface casing 20. The cement is then
permitted to harden.
A sleeve shifter is lowered through running string 36, running tool
34 and hanger 33 to the lower sleeve valve 31 in casing 22 by a
wire line not shown. The sleeve valve is opened to permit fluid
communication through the crossover of the lower ends of casings 21
and 22. This permits circulation between casings 21 and 22 for
later TFL operations. The sleeve shifter is then removed from
casing 22 and running string 36. Running tool 34 is then
disconnected from hanger 33 and the running tool and pipe strings
35 and 36 are removed from surface casing 17 and riser assembly
13.
Referring now to FIGS. 3 to 8 inclusive in which details of hanger
33 and running tool 34 are shown, hanger 33 is provided with full
open bores 40 and 41. Into the lower ends thereof are threaded
respectively casings 21 and 22. Seal nipples 42 and 43 which extend
above the top of hanger 33 are threaded into the upper end of bores
40 and 41. The outer wall of hanger 33 is slotted as at 44 to form
mud bypasses around the hanger. The hanger also is provided with
slip assemblies 45 for engagement with surface casing 17.
Positioned on and extending upwardly from the top of hanger 33 is
an orienting sleeve 46 provided with a lug slot 47. A pair of latch
recesses 48 are also provided in hanger 33. A cylindrical recess 49
which fluidly communicates with a slip actuator 50 is also provided
in hanger 33.
Running tool 34 is provided with full open bores 60 and 61, the
lower ends of which, as shown, slide over to engage sealingly about
seal nipples 42 and 43. The lower ends of running pipe strings 35
and 36 are threaded into the upper ends of bores 60 and 61. The
outer wall of running tool 34 has an orienting lug 62 which is
engageable in slot 47 of hanger 33. Bore 61 is aligned with the
bore of lower casing pipe 22 and running string 36 has a shuttle
valve 63 arranged in it. The shuttle valve is operable to fluidly
communicate bore 61 with a piston chamber 64 above and below a
latch piston 65, as shown in FIGS. 6 and 8. A piston rod 66 is
embraced by latch spring fingers 67 when latch piston 65 is in its
lower position.
Running tool 34 is also provided with a prong member 68 (see FIG.
7) on its lower end. When prong member 68 is inserted into a recess
49 in hanger 33, fluid pressure from a source of hydraulic fluid on
the drilling vessel is applied to the slip actuator assembly 50
through running string 36, a passageway 69 formed in running tool
34, prong member 68 and fluid passageways formed in hanger 33. The
fluid pressure causes slip actuator 50 to set slips 45. In the
nonactuated or nonextended position slips 45 are maintained or held
in position by shear pin 70.
When shuttle valve 63 is in the up position as shown in FIG. 6
fluid pressure communication is closed off between bore 61 and
chamber 64. When running tool 34 is connected to hanger 33 at the
water surface, latch fingers 67 in their collapsed positions are
inserted into recess 48. Fluid pressure is applied to chamber 64 to
move piston rod 66 downwardly to expand latch fingers 67 and recess
48. The running tool is thus releasably latched to the top of
hanger 33. In such an operation, plugs 71 and 72 are first removed
and then replaced after the running tool and hanger are latched
together.
In disconnecting running tool 34 from hanger 33 a string of small
diameter, e.g., 1-inch pipe 74, to the lower end of which is
attached a dart 73, is run down pipe string 36 into running tool 34
where it engages shuttle valve 63 moving it down and exposing the
fluid ports therein. Fluid pressure is applied down the annulus
between pipe 74 and running string 36 through passageway 75 into
chamber 64 (see FIG. 6) below piston 65 so as to move piston rod 66
upwardly and allow latch fingers 67 to contract in recess 48. Then
pipe 74 and dart 73 are retrieved and the running strings along
with running tool 36 are pulled. Flexible hose and prong member 68
are also removed with running tool 34.
Following cementing of casing strings 21 and 22 in the borehole and
suspending them in surface casing 20 by hanger 33, riser assembly
13 is disconnected from wellhead 12 by remote operation of
connector 14 and the riser assembly is then removed along with the
BOP stack and drilling spool 15.
Prior to running the Xmas tree assembly 85 shown in FIG. 9 the
downhole connector 34 used to connect hanger 33 to riser assembly
13 is made up on the lower end of two parallel small diameter riser
pipes 80 and 81 which are the upper extensions or sections of the
lower sections of casing pipes 21 and 22, respectively. Each riser
pipe has a safety valve such as 82 or 83 arranged in it. These
safety valves are spring actuated-hydraulically controlled such
that loss of fluid pressure, which keeps the valves open, causes
the valves to close. The safety valves are staggered one casing
joint apart, and the lowermost valve such as 82 is positioned one
joint above downhole connector 34. A plurality of hydraulic control
lines 84 pass through the Xmas tree and extend back from the
running tool 110 to the drilling vessel at the water surface. Xmas
tree 85 and a tubing tensioner 86 arranged in connector 87 is made
up on top of the dual risers 80 and 81. The Xmas tree running tool
110 which is connected to the lower end of drill pipe 8 is also
provided with a remotely operated pipe bore flow line connector 88.
Xmas tree 85 is also provided with master valves 111 to control
flow of fluids therethrough. Diverter plugs 112 are installed in
the vertical bores in the crown of the tree. The lower vertical
bores also terminate in curved branch bores forming Y-type bores in
the Xmas tree. Pipes 115 and 116 connect into the bores in the Xmas
tree below the plugs. The vertical bores permit vertical reentry to
the well through the Xmas tree whenever such operation is desired.
The entire Xmas tree assembly is lowered on drill pipe 8 and guided
by the guide frame 10 and guide lines or cables 6b. Connector 34
orients the Xmas tree with respect to hanger 33 as described
previously and also correctly aligns riser or upper section casing
pipes 80 and 81 with the lower section casing pipes 21 and 22. Also
the Xmas tree is properly directionally oriented with respect to
the manifold 7 as it is landed on the wellhead to properly position
pipelines 115 and 116 with respect to the manifold piping.
Downhole connector 34 is first operated by means of one of the
control lines in the bundle 84 to connect connector 34 and riser
pipes 80 and 81 to hanger 33. Then the Xmas tree connector 87 is
connected by hydraulic operation to wellhead 12. Casing tensioner
86 is operated to place tension on riser pipes 80 and 81 and
provide suitable casing length spaceout between downhole hanger 33
and Xmas tree 85. Tensioner 86 is also used to apply adequate
tension in riser pipes 80 and 81 to prevent any buckling of these
pipes. Such tension is applied to the riser pipes after the running
tool connector is connected to hanger 33 and the Xmas tree is
landed and connected to wellhead 12. The tension is applied also to
casing pipes 21 and 22 down to the top of the cement. Flow line
connector 88 is then operated hydraulically to connect the manifold
pipes to the Xmas tree pipes 115 and 116. The manifold pipes
connect to producing and servicing facilities at the water's
surface or on shore. Thereafter safety valves 82 and 83 are
hydraulically opened. The Xmas tree running tool is then removed
along with the drill pipe and flow line connector. A closure cap is
then run on the drill pipe using a running tool and connected to
the top of Xmas tree 85. Then the running tool and drill pipe are
removed and the removable section 89A of the antipollution spill
pan assembly 89, as shown in FIG. 10, is installed.
The well is now in condition for TFL completion procedures.
Circulation between casing strings 21 and 22 is provided by the
open crossover in lower sleeve valve 31. Completion tools can be
pumped into and out of either casing string. Perforating is now
begun with the deepest formation. As illustrated in FIG. 11, the
lower formation B has been perforated and the upper formation A is
being perforated. A rotatable perforator gun 90 provided with
locator dogs 120, firing section and detector 91 and pump cups 92
has been landed in landing nipple 24. Casing pipe 21 has positioned
in it an orienting device such as radioactive source pill 93 which
is located so as to permit firing of the rotatable gun only when
pointed away from the other casing pipe 22. The gun assembly may be
of the ratchet type and automatically fired when in a direction
away from the casing pipe 22 as illustrated in U.S. Pat.
application Ser. No. 837,248 titled "Remote Perforating of Dual
Completion Wells" by Thomas W. Childers et al. After the perforator
gun is fired it is circulated out of casing pipe 21 by pumping
fluid down casing pipe 22 through the crossover and sleeve valve 31
and up casing pipe 21 back through the Xmas tree and then through
manifold 7 to the water surface. The well is then put on production
with both zones A and B being produced through casing pipe 21, 81.
Other types of gun assemblies might also be used, as for example
one which is oriented into proper firing position by means of a cam
on or adjacent to the landing gun assembly nipple. When this gun
assembly is "cammed" into position, a safety firing mechanism is
released. Then, fluid pressure applied to the gun assembly causes a
switch to close and fire the gun.
Assuming for example an undesirable formation exists which requires
closure due to high salt water or gas production. A patch tool 95
as seen in FIG. 12 is pumped down casing pipe 21 by a locomotive
means such as a running tool with swab cups (not shown) and landed
in landing nipple 26 above formation B. The hollow tube in patch
tube 95 is equipped with running and retrieving necks and the tube
section is flexible enough to be pumped through the curvatures in
the pipe strings. The tube blanks off formation B; however, being
hollow, circulation is permitted between the two casing pipes 21
and 22 through sleeve valves 31. The running tool is then pumped
out of the well.
Gas-lift valves are not installed until required. As shown in FIG.
13 casing pipes 20 and 21 and sleeve valves 29 and 30 become
gas-lift mandrels. Valve 29 is provided with a landing recess 29A
and sealing rings 29B and 29C which are positioned above and below
the crossover, respectively. Sleeve 30 is also provided with
landing recess 30A and sealing bores 30B and 30C. A gas-lift
assembly consisting of two interconnected gas-lift valves 100 and
101, running tool 102, sleeve shifter 103 and locomotive cup 104
are pumped down service casing pipe 22 until sleeve shifter 103 is
below the lowermost sleeve valve or gas-lift mandrel 30.
Circulation is then reversed by circulating fluid down casing pipe
21 and pumping the gas-lift valve assembly upwardly in casing pipe
22. As the shifter moves through valve 30 it causes the sleeve
therein to shift upwardly to the open position and gas-lift valve
101 is deposited and latched in nipple 30A as shown in FIG. 14. As
the gas-lift valve assembly moves upwardly, the sleeve valve 29 is
opened and gas-lift valve 100 is likewise deposited and latched in
nipple 29A. The sleeve shifter 103 and locomotive means 104 is then
pumped out of the well. Gas-lift for the formations can then be
obtained by supplying gas down casing pipe 22 and by way of valves
101 and 100 and the respective crossovers to casing pipe 21.
* * * * *