U.S. patent application number 15/516199 was filed with the patent office on 2017-10-12 for well completion system and method, drilled well exploitation method, use of same in the exploitation/extraction of drilled wells, packaging capsule, telescopic joint, valve and insulation method, and valve actuation system, selection valve and use of same, connector and electrohydraulic expansion jo.
This patent application is currently assigned to Geo Innova Consultoria e Participacoes Ltda.. The applicant listed for this patent is Geo Innova Consultoria e Participacoes Ltda., Teles e Nogueira Consultoria Ltda.. Invention is credited to Doneivan Fernandes FERREIRA.
Application Number | 20170292326 15/516199 |
Document ID | / |
Family ID | 55629183 |
Filed Date | 2017-10-12 |
United States Patent
Application |
20170292326 |
Kind Code |
A1 |
FERREIRA; Doneivan
Fernandes |
October 12, 2017 |
WELL COMPLETION SYSTEM AND METHOD, DRILLED WELL EXPLOITATION
METHOD, USE OF SAME IN THE EXPLOITATION/EXTRACTION OF DRILLED
WELLS, PACKAGING CAPSULE, TELESCOPIC JOINT, VALVE AND INSULATION
METHOD, AND VALVE ACTUATION SYSTEM, SELECTION VALVE AND USE OF
SAME, CONNECTOR AND ELECTROHYDRAULIC EXPANSION JOINT
Abstract
The present invention describes a completion system for drilled
wells having valves mechanisms, drives, sensors and devices able to
promote an exploration of wells, safer, more efficient and,
therefore, more economically viable. Specifically, the present
invention comprises a system allowing the installation of smart
completion in single or multiple producing zones, comprising valves
mechanisms, drives, sensors, between other devices disclosed by the
present invention. The present invention is in the fields of
petroleum engineering and mechanic engineering.
Inventors: |
FERREIRA; Doneivan Fernandes;
(Rio de Janeiro, BR) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Geo Innova Consultoria e Participacoes Ltda.
Teles e Nogueira Consultoria Ltda. |
Rio de Janeiro
Rio de Janeiro |
|
BR
BR |
|
|
Assignee: |
Geo Innova Consultoria e
Participacoes Ltda.
Rio de Janeiro
BR
Teles e Nogueira Consultoria Ltda.
Rio de Janeiro
BR
|
Family ID: |
55629183 |
Appl. No.: |
15/516199 |
Filed: |
October 1, 2015 |
PCT Filed: |
October 1, 2015 |
PCT NO: |
PCT/BR2015/050166 |
371 Date: |
March 31, 2017 |
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 43/12 20130101;
E21B 47/00 20130101; F04D 13/10 20130101; F16L 27/00 20130101; F16K
15/00 20130101; E21B 17/22 20130101; F16K 31/12 20130101; E21B
33/0355 20130101; E21B 43/128 20130101; E21B 43/106 20130101; E21B
7/203 20130101; E21B 47/01 20130101; E21B 43/123 20130101; E21B
7/04 20130101; E21B 34/10 20130101; E21B 41/0021 20130101; E21B
43/00 20130101 |
International
Class: |
E21B 7/20 20060101
E21B007/20; E21B 47/01 20060101 E21B047/01; E21B 43/12 20060101
E21B043/12; E21B 17/22 20060101 E21B017/22; E21B 7/04 20060101
E21B007/04 |
Foreign Application Data
Date |
Code |
Application Number |
Oct 1, 2014 |
BR |
BR102014024580-4 |
Oct 1, 2014 |
BR |
BR102014024581-2 |
Oct 3, 2014 |
BR |
BR102014024851-0 |
Oct 3, 2014 |
BR |
BR102014024854-4 |
Oct 3, 2014 |
BR |
BR102014024858-7 |
Nov 14, 2014 |
BR |
BR102014029576-3 |
Nov 17, 2014 |
BR |
BR102014028656-0 |
Feb 6, 2015 |
BR |
BR102015002643-9 |
Claims
1. A completion system for drilled wells comprising: a) valves
mechanisms; b) drives; c) sensors; d) an expandable joint for
adjusting the distance between system components; e) a shut-off
valve; f) a system of controlling the shut-off valve drive; g) a
control valve of operation and maintenance; and h) a
decoupling/expandable electro-hydraulic connector.
2. An exploration system of a drilled well comprising elevation
means of fluid in the drilled well, wherein the said elevation
means is a set of submerged centrifugal pumps and/or a system of
gas lifts, the elevation means being arranged inside a capsule (IT)
housed in a removable manner inside the drilled well.
3. An exploration system of multiple producing zones in drilled
well comprising: a) at least two extraction regions, wherein the
extraction regions are isolated from each other in the annular
region; and b) an elevation assembly (PA) arranged inside a coating
capsule (IT); wherein the annular region comprises a perimeter
clearance existing between the elevation assembly (PA) and the
inner wall of the coating capsule (IT).
4. A method of extraction in a drilled well with an exploration
system of multiple producing zones, wherein the system is provided
with a locators feed-thru (6) with a packer seal bore (11) and an
elastomer for sealing.
5. A capsule for conditioning components of an exploration system
of a drilled well comprising a hollow inner region and a housing
outer region inside the drilled well, the capsule: a) housing
elevation and control components for extracting the fluid contained
in the drilled well; and b) allowing the simultaneous mounting and
removal of the said elevation and control components for extracting
from inside the well.
6. An exploration method in a drilled well with a capsule for
conditioning components of the exploration system comprising the
following steps: a) inserting a coating capsule (IT) inside a
drilled well; b) inserting an elevation assembly (PA) inside the
coating capsule (IT).
7. A telescopic joint for adjusting a mounting distance between
components of an exploration system of a drilled well comprising a
linear extension means for connecting components of an elevation
assembly (PA) and/or for adjusting the total length of the
elevation assembly (PA).
8. An isolating valve for an exploration system of a drilled well
comprising a means for opening and closing a drive through pressure
control applied in an annular space (AE) of the valve.
9. (canceled)
10. (canceled)
11. (canceled)
12. (canceled)
13. An electro-hydraulic connector for an exploration system of a
drilled well comprising: a) at least one internal assembly (22);
and b) at least one external assembly (23) wherein: the internal
assembly (22) is able to be coupled to external assembly (23); the
internal assembly (22) has electrical connections (87 and 80) and
hydraulic connections (76); the external assembly has electrical
connections (87 and 80) and hydraulic connections (76); and the
hydraulic connections are allocated in a way they coincide when the
coupling takes place.
14. An electro-hydraulic expansion joint comprising: a) a lower
tubular component provided with: a thread in a lower part for
connecting into an electro-hydraulic connector; a sealing in an
upper part between the lower tubular component and an inner
cylinder; a hexagonal lock system for preventing an internal column
from turning and for allowing torque transmission between the lower
tubular component and an upper tubular component; a lock system for
column decline with an extension fixed in a totally closed
position; an external ring (upper and lower) for aligning external
hydraulic and electric lines; bars for filling an empty space
between the external hydraulic and electric lines; and a protection
liner for internal hydraulic and electric lines, b) the upper
tubular component provided with: a cylindrical top (95) with a
thread in the center for an inner sliding tube; a thread for
connection to a production column (96); and peripheral threads (97)
for connecting hydraulic and electric lines.
15. (canceled)
16. An exploration method in a drilled well comprising using an
electro-hydraulic connector comprising: a) at least one internal
assembly (22); and b) at least one external assembly (23) wherein:
the internal assembly (22) is able to be coupled to external
assembly (23); the internal assembly (22) has electrical
connections (87 and 80) and hydraulic connections (76); the
external assembly has electrical connections (87 and 80) and
hydraulic connections (76); and the hydraulic connections are
allocated in a way they coincide when the coupling takes place.
17. An exploration method in a drilled well comprising using an
electric-hydraulic joint comprising: a) a lower tubular component
provided with: a thread in a lower part for connecting into an
electro-hydraulic connector; a sealing in an upper part between the
lower tubular component and an inner cylinder; a hexagonal lock
system for preventing an internal column from turning and for
allowing torque transmission between the lower tubular component
and an upper tubular component; a lock system for column decline
with an extension fixed in a totally closed position; an external
ring (upper and lower) for aligning external hydraulic and electric
lines; bars for filling an empty space between the external
hydraulic and electric lines; and a protection liner for internal
hydraulic and electric lines, b) the upper tubular component
provided with: a cylindrical top (95) with a thread in the center
for an inner sliding tube; a thread for connection to a production
column (96); and peripheral threads (97) for connecting hydraulic
and electric lines.
Description
FIELD OF THE INVENTION
[0001] The present invention refers to an exploration system of
drilled wells and a method for extracting fluids from the said
drilled wells. The present invention is in the fields of petroleum
engineering, and mechanic engineering.
BACKGROUND OF THE INVENTION
[0002] Oil prospecting has been the subject of long studies and
major technological contributions in recent decades, despite the
emergence of new sources of energy use, the prognostics point out
many decades ahead of great importance of this type of natural
resource.
[0003] The smart completion of oil producing wells is a type of
completion that allows producing several producing zones together,
monitoring and controlling the said producing zones remotely and
individually. The use of smart completion enables exploration of
marginal reserves and acceleration of hydrocarbon production
through joint and controlled production of reservoirs,
significantly increasing the recovery factor of the field.
[0004] Common oil producing wells, or having smart completion, need
at some point, mechanisms to supplement the loss of natural
pressure of rocks bearing hydrocarbons. The methods are quite
varied, but the gas-lift and Submerged Centrifugal Pumping (BCS)
are usually preferred when the wells are submarine and/or with high
flow. Depending on the oil viscosity, either of these two methods
makes a choice. For high viscosities and high flow rates, BCS is
invariably the chosen lifting method.
[0005] For proper monitoring of the pressures and temperatures of
smart completions in oil reservoirs, electronic sensors are
installed in the production column (as deep as possible). Usually
this occurs below the capsule where the BCSs are housed. In this
way, it is necessary to pass electric cables and hydraulic lines
and/or chemical products, which connect the devices to the surface.
The most common method of installing these lines and cables is by
attaching them to the production columns with metal clips on each
sleeve of the tubes. The passage through the capsule, externally,
requires a well with larger internal diameters so as to be able to
accommodate the capsules with the clamps which will fasten such
lines and cables thereto. Often, even with larger well diameters,
this is possible, requiring such components to be passed through
capsules internal part, resulting in other more constructively
complex problems.
[0006] Normally, to perform electric cables and hydraulic lines
passage inside the capsule, it is necessary to use connectors
and/or joints of wet expansion electro-hydraulic connections to
interconnect the upper part with the lower one of the capsule. In
addition, it is necessary to adjust the length of the whole
submerged electric pump assembly with the capsule length. That
means, as the BCS assembly will have to adjust in two fixed points
inside the capsule, it is necessary to use a wet electro-hydraulic
expansion joint, which the oil market also searches for
development.
[0007] Another major problem faced with conventional compositions,
that is, when the submerged electric pump assembly falls joint to
the capsules, it is the great probability of objects, which remain
in the well, resulting from the production columns, such as metal
clamping hooks of the power electric cable, to fall inside the
well, mainly in horizontal wells and of great slope. In the column
drag, when it is removed for pump changes, one or more hooks may
break and fall to the bottom of the well, on the gravel packer.
This type of event usually generates the need for complex special
operations, called "fisheries", difficult to succeed, with a high
risk of well loss. This type of problem is inherent to the BCS
lifting method and it is necessary to live with such risk in the
best possible way, betting heavily on the reliability of the hook
materials.
[0008] In addition, the accidental fall of objects in the well is
frequent (it is part of the daily operation), but its consequences
are disastrous. Whenever this occurs, always accompanied by great
uncertainties, the chances of great economic losses in the
identification of the fallen object, called "fish", and its
subsequent removal, are significant.
[0009] Another important aspect, which should be mentioned, is that
the average useful life of BCS is 2 years. That is, in this average
time interval, a probe workover must occur for BCS replacement that
has stopped working. This workover lasts an average of 45 days and,
in addition to the high expenses with "probe diaries", it is
necessary to internalize the time that the well has stopped
producing (loss of profit), awaiting probe for workover. To
minimize this, the well is usually equipped with BCS and gas-lift
mandrel, which will start as soon as the pump stops working, while
the probe does not reach. This time can be long and depends on the
demand for probes in the period demanded.
[0010] These mandrels are usually positioned below the capsule
where the BCS are housed. This prevents its access with slickline,
for valve exchanges, as they are below the pumps. The reason for
not being positioned above is the possibility of being able to use
them also for reverse circulation, "annular.times.column", removing
the largest possible volume of oil from the production column,
during workovers for pump exchange. Due to its positioning in an
inaccessible place for slickline operation, any problems with the
valves can only be solved by removing the entire column with the
BCS assembly. It should be noted that gas-lift valves operate
optimally with large volumes of gas but they are poorly tolerant
under fluid flow scenarios at high flow rates. This is the main
reason for failures when reverse circulation is required to "dampen
the well" during a workover, limiting the circulation flow,
resulting in large losses of probe times (probes are rented per
hour).
[0011] In view of the scenario that was exposed, there is a great
impasse in this sector of oil production. While smart completion
increases the well recovery factor by prolonging the time the well
will require workovers, at the cost of expensive and complex
equipment, the use of BCS inevitably requires the use of probe
workovers in the wells to the pump change. This scenario of doubts
and uncertainties hinges on oil prospecting companies, how to
reconcile the use of more complex equipment to reduce the number of
workovers with other equipment that increase the number of
workovers due to the short lifespan, especially the BCS
assembly.
[0012] Searching for the prior art, the following documents
regarding the theme were found:
[0013] Document CN103382835 discloses one completion system of
multiple producing zones provided with packers separating the said
producing zones in order to provide a segregation between the said
producing zones. Each producing zone has one smart control device,
for example, the first producing zone is controlled by one first
smart control device, the second producing zone is controlled by a
second smart control device, and so on. The production column is
associated to all producing zones, but it produces fluids only from
that zone where the system decides to produce. This invention's
teachings refer on an automated system to detect which zones is
producing fluids with less amount of undesired fluids mixed to the
fluids of interest. Such document does not suggest how to reconcile
the fluids prospection from wells with smart completion using smart
mechanisms of high technology, in order to reduce the costs with
the wells; mainly those associated to the exchange of the submerged
centrifugal pumping assembly and the workovers with probe.
[0014] Document U.S. Pat. No. 8,127,845 discloses a completion
system of multiple producing zones of hydrocarbons based on the
selective segregation of zones that will produce fluids. Through a
sliding sleeve, the operator commanding a rod of service is able to
isolate a producing zone misaligning the holes present in the inner
capsule of the holes present in the outer tube, while when it is
desired to produce from another producing zone, this same operator
aligns the said holes such that the fluids may move up through the
production column. The said alignment and misalignment of holes is
made with the service rod and its outer recess that, in contact
with the inner recess present in the sliding sleeve transmits the
axial movement axial of the service rod in order to align or
misalign holes. This document discloses some facilities in the
completions, since it is possible to produce several producing
zones in a joint or separated manner. For example, if in a certain
producing zone the pressure is too higher regarding a second
producing zone, it is possible to produce from this producing zone
of greater pressure until pressures are balanced, and the
hydrocarbons formation occurs simultaneously between several
producing zones. Further, it is possible to drain undesired fluids
(water, mud, etc) of a certain producing zone, while the further
ones are closed, avoiding possible contamination. This document
does not disclose a form to reduce the workover time of oil
producer wells, mainly those provided with smart completions. Such
document also does not disclose a mean to remove the submerged
centrifugal pumping assembly in wells with smart completion without
the risk of complex and onerous fisheries.
[0015] Document US20140083684 discloses a completion system of
hydrocarbons producing wells that permeate through multiple
formation. The system, among several embodiments presented, is
based on packers dividing multiple formation zones and, through a
pressure sensor analyzing the pressure in the said formation zone
send collected information through the cable. The said information
is used to control the flow that is formed from each one of the
production zones. Conventional equipments of a completion include
gravel, pressure sensor, filtering screen and, mainly, a flow
control valve driven by one hydraulic control. The flow control
valve is able to totally close the formation zone, or simply
restrict part of the production flow, according to the moment
needs. The system of the present document has also a device for
pumping the production flow, safety valve and formation total
isolating valve. The said document does not disclose how to produce
multiple formation zones reconciling the minimum need of workover
with probe, using the submerged centrifugal pumping equipment, with
short lifespan.
[0016] Document U.S. Pat. No. 8,651,188 refers a gas lift valve
comprising longitudinal tubular structure provided with an entry
and an output, a flow path between the entry and the output, and
one flow tube arranged inside the tubular structure. Such document
has as disadvantage the fact of it does not provide a solution for
fluids path of different densities and by the fact of it does not
provide a mean to increase the gas flow.
[0017] Document U.S. Pat. No. 8,662,184 discloses a capsule system
for coating a set of two submerged pumps that may operate
simultaneously or in backup system. The said document highlights
about the importance of using two pumps in a completion due to the
difficulties associated to the said pumps exchange. Besides
suggesting that the capsule assembly must be removed from well
coating internal part for maintenance, the inventor did not preview
facilities in the removal of the pumps assembly from inside the
said capsule, such that time-consuming jobs for such operation are
necessary.
[0018] In addition to the considerable difference to the present
invention, the capsule does not have any facility when removing the
pump assembly, a further point away from the present invention is
the fact that the said capsule comes out of the oil well to replace
the pump assembly, since this capsule is joint with the remainder
of the assembly.
[0019] Document U.S. Pat. No. 7,150,325 has a system of submerged
pump comprising a primary coating capsule having internally a
capsule of main housing, an inner pump to this and an outer casing
involving the said primary coating in order to form an annular
space. The primary capsule has in its lower end a polished hole
with a sleeve or flapper type valve. The primary coating capsule is
fixed to the well through its upper end housing in the primary
support. The stamp provides water-tightness to the upper end fit.
The main capsule have sealing stamps and a check valve. BCS
assembly is located inside the main housing capsule and comprises
more specifically, a centrifugal pump, fluids inlet in its lower
portion and an engine below the said input. BCS assembly has one
adaptor connecting the upper part of the centrifugal pump to the
member and this said member connects to the capsule support. The
member and the adaptor may be one single piece. The fluid path to
outside is made through vertical path and through side path. When
the BCS assembly replacement is necessary, one ROV open the upper
cap, connects a tool to the hole and, through the lifting system,
removes the BCS assembly together with the main housing capsule. A
noticeable difference between this document and the present
invention is in the fact that BCS assembly is removed together with
its coating capsule, besides other capsule is internal to the
production well, more weight will be lifted and consequently larger
machines are needed, in addition to not being spared any work,
since the pump should be disassembled from the said capsule. Other
noticeable difference in this document is the fact that it does not
preview a secondary system for petroleum lifting, as for example
the gas-lift.
[0020] Thus, from the literature researched, no documents were
found to be anticipating or suggesting the teachings of the present
invention, so that the solution proposed here has novelty and
inventive activity compared to the prior art.
SUMMARY OF THE INVENTION
[0021] Thus, the present invention discloses a completion system
for drilled wells having valves mechanisms, drives, sensors and
devices able to promote an exploration of wells, safer, efficient
and, therefore, more economically viable.
[0022] In a first object, the present invention discloses a
completion system for drilled wells comprising:
[0023] a. valves mechanisms;
[0024] b. drives;
[0025] c. sensors;
[0026] d. expandable joint for adjusting the distance between
system components;
[0027] e. shut-off valve;
[0028] f. system for controlling shut-off valve drive;
[0029] g. control valve of operation and maintenance;
[0030] h. decoupling/expandable electro-hydraulic connector.
[0031] In a second object, the present invention discloses an
exploration system of drilled well comprising lifting means of
fluid contained in drilled well, being the said lifting mean a set
of submerged centrifugal pump and/or gas lift system, the lifting
mean being arranged inside the capsule (IT) housed in removable
manner inside the drilled well.
[0032] In a third object, the present invention has an exploration
system of multiple producing zones in drilled well comprising:
[0033] a. at least two extraction regions, being the extraction
regions isolated from each other in the annular region; and
[0034] b. lifting assembly (PA) arranged inside the capsule
(IT);
[0035] being the annular region a perimeter clearance existing
between the lifting assembly (PA) and the inner wall of the capsule
(IT).
[0036] In a forth object, the present invention has a method of
extraction in drilled well having exploration system of multiple
producing zones where the said system is provided with locators
feed-thru (6) with packer seal bore (11) and elastomer for
sealing.
[0037] In a fifth object, the present invention discloses a capsule
for conditioning components of exploration system of drilled well
comprising a hollow inner region and a housing outer region inside
the drilled wells, the said capsule being able of:
[0038] a. housing the lifting and control components of fluid
extracting contained in the drilled well; and
[0039] b. allowing the simultaneous mounting and removal of the
said lifting and control components of extracting inside the
well.
[0040] In a sixth aspect, the present invention has an exploration
method in drilled well with capsule for conditioning components
comprising the following steps:
[0041] a. inserting a coating capsule (IT) inside a drilled
well;
[0042] b. inserting a lifting assembly (PA) inside the coating
capsule (IT).
[0043] In a seventh object, the present invention has a telescopic
joint for adjusting the mounting distance between components of an
exploration system of drilled well comprising linear extension
means for connecting components of an lifting assembly (PA) and/or
for adjusting the total length of lifting assembly (PA).
[0044] In an eighth object, the present invention claims an
isolating valve for exploration system of drilled well comprising
opening and closing drive through pressure control applied in the
annular space (AE).
[0045] In a ninth object, the present invention has a method for
closing and isolating formations in drilled well comprising at
least a step wherein a shut-off valve (CV) is controlled by
hydraulic means.
[0046] In a tenth object, the present invention discloses a system
for controlling the drive of isolating valve for exploration system
of drilled well comprising opening and closing drive through:
[0047] a. pressure control applied in the annular space (AE);
and
[0048] b. pressure and/or drag resulting from kinetic energy
imposed to high fluid.
[0049] In a eleventh object, the present invention brings a
selecting valve of operation fluid comprising a body of the
selecting valve (65) provided with two passages in order to
segregate the flow of a primary fluid of the flow of a secondary
fluid, being the primary fluid provided with at least one property
different from the secondary fluid.
[0050] In a twelfth object, the present invention claims the use of
selecting valve for controlling operation and maintenance of the
gas lift equipment where the selecting valve is as defined in this
description and is intended to an exploration system of drilled
well.
[0051] In a thirteenth object, the present invention discloses an
electro-hydraulic (EP) connector for exploration system of drilled
well comprising:
[0052] a. at least one internal assembly (22); and
[0053] b. at least one external assembly (23)
[0054] wherein: [0055] the internal assembly (22) is able to couple
to the external assembly (23); [0056] the internal assembly (22)
has electrical connections (87 and 80) and hydraulic connections
(76); [0057] the external assembly has electrical connections (87
and 80) and hydraulic connections (76); and [0058] the connections
are allocated in order to coincide when the coupling takes
place.
[0059] In a fourteenth object, the present invention brings the
electric-hydraulic expansion joint comprising:
[0060] a. tubular lower component provided with: [0061] thread in
the lower part for connecting into the electro-hydraulic connector;
[0062] sealing in the upper part between the lower component and
the inner cylinder; [0063] hexagonal lock system able to prevent
the internal column turn and to allow the torque transmission
between the lower and upper component; [0064] lock system for
column decline with the extension fixed in the totally closed
position; [0065] external ring (upper and lower) for aligning
external hydraulic and electric lines; [0066] bars for filling the
empty space between external hydraulic and electric lines; and
[0067] protection liner of the internal hydraulic and electric
lines,
[0068] b. tubular upper component provided with: [0069] cylindrical
top (95) with thread in the center for the inner sliding tube;
[0070] thread for connection into the production column (96); and
[0071] peripheral threads (97) for connecting hydraulic and
electric lines.
[0072] In a fifteenth object, the present invention has an
exploration method in drilled well using one electro-hydraulic
connector and/or electric-hydraulic joint as defined in this
description.
[0073] In a sixteenth and last object, the present invention has
the use of exploration/completion system of drilled well, being the
system as anyone defined above being intended to hydrocarbons
extraction in drilled wells, in special petroleum.
[0074] These and other objects of the invention will be immediately
valued by those skilled in the art and by the companies with
interests on the segment, and will be detailed described for its
reproduction in the following description.
BRIEF DESCRIPTION OF THE FIGURES
[0075] Aiming to better define and clarify the content of the
patent present application, the present figures are presented.
[0076] FIG. 1 illustrates a first main tube (MT1) for coating the
drilled wells. Such first main tube (MT1) has packer seal bore (11)
in its lower portion, in order to promote the control of the said
drilled well.
[0077] FIG. 2 discloses an embodiment for the first inner capsule
(IT1) that will be used in a well having a single producing zone
(7).
[0078] FIG. 3 illustrates a first lifting assembly (PA1) to be used
with the first inner capsule (IT1) in drilled well having one
single producing zone (7).
[0079] FIGS. 4.1 and 4.2 illustrate a sequence of removal from the
first lifting assembly (PA1) for wells of a single producing zone
(7). More specifically, FIG. 4.1 illustrates one well having the
first lifting assembly (PA1) inserted into the first inner capsule
(IT1), and FIG. 4.2 illustrates how is the removal of the first
lifting assembly (PA1) without removing the first inner capsule
(IT1).
[0080] FIG. 5 illustrates an embodiment of the present invention,
with a smart completion provided with production column (1) with
the second inner capsule (IT2) and second lifting assembly
(PA2).
[0081] FIG. 6A and 6B depict the production column (1) sectioned
into two parts for a better detailing of its inner components.
[0082] FIGS. 7, 8 and 9, illustrate, respectively, the second
lifting assembly (PA2) decoupled from the second inner capsule
(IT2) that, in turn, is decoupled from the second main tube
(MT2).
[0083] The sequence of FIGS. 10.1, 10.2 and 10.3 illustrate a
step-by-step of how the handling tool (10) acts in the inner valve
(13), in order to allow the fluids to be produced from the
perforation region (14).
[0084] FIG. 11 depicts details of the submerged centrifugal pumping
assembly, called pumping device (4).
[0085] FIG. 12 discloses an embodiment for electro-hydraulic
telescopic joint (TJ) used in the production column (1), as the
present invention teachings.
[0086] FIGS. 13 and 14 illustrate a comparison of drilled wells
having production columns (1) and telescopic joint (TJ).
Specifically, FIG. 13 illustrates a well wherein the production
column is not equipped with telescopic joint (TJ), and FIG. 14
illustrates a production column (1) provided with the said
telescopic joint (TJ).
[0087] FIG. 15 discloses an embodiment of the shut-off valve (CV)
used in the production column (1) to stop the fluids production
from a drilled well.
[0088] FIG. 16 illustrates operation details of an embodiment of
the shut-off valve (CV) of the present invention.
[0089] FIG. 17 illustrates details of how the mechanism acting
directly in the shut-off valve (CV) of the present invention
operates.
[0090] FIG. 18 illustrates an exploded view of the components
present In one embodiment for shut-off valve (CV), as the present
invention teachings.
[0091] FIG. 19 illustrates an embodiment for the mechanism
responsible for the fact that the shut-off valve (CV) moves in one
single direction.
[0092] FIG. 20 illustrates a side view of the shut-off valve (CV),
according to the present invention.
[0093] FIGS. 21.1, 21.2 and 21.3 illustrate the sequence of driving
the shut-off valve (CV) associated to a control mechanism (CM).
Particularly, FIG. 21.1 illustrates the shut-off valve (CV) in an
open position and with the drilled well producing fluids. The image
21.2 illustrates one instant wherein, after the fluids production
stop, the inner sleeve (17), by acting a first actuation mean (18),
acts the control mechanism (CM). The image 21.3 illustrates one
instant wherein, through the pressure inserted in the annular
region of the production column (1), the control mechanism (CM)
returns opening the shut-off valve (CV).
[0094] FIGS. 22.1, 22.2 and 22.3 illustrate a second embodiment for
the shut-off valve (CV), where the shut-off valve body (46)
controls only the ducts interconnecting the annular space (AE) to
the duct carrying the produced fluids.
[0095] FIG. 22 illustrates one comparison in each driving condition
of a valve execution of smart completion gradually closing of the
present invention.
[0096] FIG. 23 illustrates an embodiment for selective valve (SV)
that is installed in the first or second capsule (IT1 or IT2),
according to the present invention teachings. In this image, the
selective valve (SV) allows the fluids path through a primary hole
(19).
[0097] FIG. 24 shows an embodiment for selective valve (SV) of the
present invention, where the fluids path is being allowed by one
secondary hole (20).
[0098] FIG. 26 depicts an embodiment of the selective valve (SV) of
the present invention applied in a production column (1), in order
to promote fluids segregation that enter into the gas lift mandrel
(21).
[0099] FIG. 26A has the external assembly (23) of the
electro-hydraulic (EP) connector in the disconnected position,
according to the present invention teachings.
[0100] FIG. 26B has the internal assembly (22) of the
electro-hydraulic (EP) connector of the present invention in the
disconnected position.
[0101] FIG. 27 has the electro-hydraulic (EP) connector of the
present invention in the coupling position of the inner (22) and
outer (23) assemblies.
[0102] FIGS. 28.1 and 28.2 illustrate the sequence for removing the
pumping device (4) of drilled wells having production columns (1)
and electro-hydraulic (EP) connector. Specifically, FIG. 28.1
illustrates one drilled well with the coupled electro-hydraulic
(EP) connector and pumping device (4) attached to the completion
remaining. But FIG. 28.2 illustrates the electro-hydraulic (EP)
connector disconnection, where it is possible to note how the
pumping device (4) removal works.
[0103] FIG. 29 illustrates a second embodiment for telescopic joint
(TJ) of the present invention. This mechanism is able to adapt to
variations of length experienced in the production column (1) by
slipping the outer tube (24) regarding the inner tube (25). A
hexagonal lock (26) ensures the torque transmission between outer
and inner tubes. This mechanism is fixed to the upper part of the
electro-hydraulic (EJ) connector through the outer thread (27).
DETAILED DESCRIPTION OF THE INVENTION
[0104] The present invention discloses a completion system for
drilled wells having valves mechanisms, drives, sensors and devices
able to promote an exploration of wells, safer, more efficient and,
therefore, more economically viable.
[0105] It is, therefore, one first object of the present invention
to provide a completion system for drilled wells comprising: [0106]
a. valves mechanisms; [0107] b. drives; [0108] c. sensors; [0109]
d. expandable joint for adjusting the distance between system
components; [0110] e. shut-off valve; [0111] f. system for
controlling shut-off valve drive; [0112] g. control valve of
operation and maintenance; [0113] h. decoupling/expandable
electro-hydraulic connector.
[0114] It is a second object of the present invention to provide an
exploration system of drilled well comprising lifting means of
fluid contained in drilled well, being the said lifting mean a
submerged centrifugal pump assembly and/or gas-lift system, the
lifting mean being arranged inside the capsule (IT) housed in a
removable manner inside the drilled well.
[0115] It is a third object of the present invention to provide an
exploration system of multiple producing zones in drilled well
comprising: [0116] a. at least two extraction regions, being the
extraction regions isolated from each other in the annular region;
and [0117] b. lifting assembly (PA) arranged inside the capsule
(IT); being the annular region in a perimeter clearance existing
between the lifting assembly (PA) and the capsule inner wall
(IT).
[0118] It is a forth object of the present invention to provide a
method of extraction in drilled well having exploration system of
multiple producing zones where the said system is provided with
locators feed-thru (6) with packer seal bore (11) and elastomer for
sealing.
[0119] The system of smart complementation proposed comprises
multiple producing zones, locators feed-thru (6) with packer seal
bore (11) and elastomer for sealing.
[0120] The present invention has a smart completion system with at
least two producing zones, since the separation of the producing
intervals in sub-zones allows a greater control of each interval
and, even producing together, it optimizes the hydrocarbons
recovery of each zone. This is because as Smart Completion valves
work by restricting, from full opening to full closing, each
interval, uniformizing as each zone's flow pressures.
[0121] The total recovery of hydrocarbons, when producing the
intervals together, presents economic advantage that significantly
overcomes the recovery obtained with the individualized production
of each interval until its complete exhaustion. This demonstrates
one of the advantages of using smart completions, in addition to
the demonstrated economy with workovers using the prior art probes,
it is also possible to increase the recovery factor of the oil
reservoirs, i.e., higher recovery rates with lower production
costs.
[0122] Although the petroleum industry already has various forms of
smart completion, most of them depend on the application of feed
thru packers for insulation between producing zones, causing each
installation point to have a column squeeze. Electric cables,
hydraulic lines and chemicals path is made inside the solid body of
these packers that must provide hydraulic seal at the path points.
As there is still no consolidated technique of wet
electro-hydraulic connectors/disconnectors, the use of these
completions today is considered infeasible.
[0123] The proposed invention, however, allows the use of smart
completions of multiple zonas without the need of packers feed
thru. Instead, such elements are replaced by locators feed thru,
which elastomeric elements seal polished areas (seal bores) inside
the capsule, however, not providing anchorage. The smart completion
recovery is, thus, simples and no element (such as: valves,
pressure and temperature sensors, chemical injection mandrels) need
to be replaced, it its respective tests on the surface are
positive.
[0124] The insulation of the producing intervals is performed
through elastomers as the current ones "Swelling Packer" or other
similar elements, with the same function. These go down with the
capsule and should not provide anchorage against the coated
well.
[0125] In an embodiment, the present invention is combined to a
system for extracting petroleum comprising at least: i) a coating
capsule; ii) a submerged electric pump assembly; wherein the
submerged electric pump assembly is installed independently inside
the coating capsule.
[0126] The extraction capsule comprises: internally polished tube,
coating tube, gas lift mandrel housing with selective entry for gas
and fluid, formation isolating valve, retention valve, and a
sealing anchor with elastomeric elements.
[0127] The submerged electric pump assembly comprises: electric
cable, pump, electric engine, tubes, and telescopic joint.
[0128] Due to system uses an electric pump, it becomes necessary
one power electric cable to go down coupled with the production
column, attached to the same by clamps, to provide electrical
energy for engines moving the centrifugal pumps.
[0129] All this submerged electric pump assembly is inside the
coating water-tight capsule, isolating the formation produced
fluids from the rest of the well, called annular space (space
formed between the production coating and the production column+BCS
capsule). The higher the flow produced, the greater the power
required by the engines, which will have larger external diameters
and the capsules that will house them will also need to be
larger.
[0130] In workovers operations for exchanging the submerged
electric pump assemblies, the non-solid capsule remains in the
well, allowing any object that falls into the well to be easily
recovered (since they will be inside the capsule). This very
important aspect prevents such objects from falling above the
"gravel packer" which would result in the need for a special
complex and risky "fishing" operation, which could lead to the loss
of the well.
[0131] With respect to the stops of the submerged electric pump
assemblies for damage, the option to continue producing the well
using gas-lift can be used with the gas injected by the annulus
entering the gas-lift mandrel housing to reach the gas-lift
mandrel. The gas-lift mandrel housing can direct the flow into the
mandrel or into the column, depending on the flow of pumped fluids.
That is, the system of the present invention is selective regarding
the pumped flows and the types of fluids: whether gas or liquid.
This is critical for preserving high-speed gas-lift valves
generated by fluids pumped into the annular space during
damping.
[0132] It is a fifth object of the present invention to provide a
capsule for conditioning components of the exploration system of
drilled well comprising a hollow inner region and a housing outer
region inside the drilled wells, the said capsule being able of:
[0133] a. housing lifting and control components for extracting
fluid contained in the drilled well; and [0134] b. allowing
simultaneous mounting and removal of the said lifting and control
components for extracting from well inside part.
[0135] The proposed system aims to overcome all deficiencies of the
current systems with joint capsule with significant economic
advantage and mitigation of problems risks related to special
operations of complex "fisheries".
[0136] The proposed system comprises at least: i) one coating
capsule; ii) one submerged electric pump assembly; wherein the
submerged electric pump assembly is independently installed inside
the coating capsule.
[0137] The proposed system, when disentangling the capsule of the
submerged electric pump assembly, results in a greater flexibility
in the completions with simpler mounts in the surface. Thus, the
"non-joint capsule" is mounted and declined in the well, just after
the lower completion decline, normally composed of screens of the
"gravel pack" system (isolating valve of the formation and "gravel
packer").
[0138] The method for extracting petroleum comprises the steps of
inserting a non-joint capsule inside the drilled well; and
inserting a submerged electric pump assembly inside the non-joint
capsule.
[0139] In one embodiment, the extraction capsule comprises:
internally polished tube, coating tube, gas-lift mandrel housing
with selective entry for gas and fluid, formation isolating valve,
retention valve, and a sealing anchor with elastomeric
elements.
[0140] In one embodiment, the submerged electric pump assembly
comprises: electric cable, pump, electric engine, tubes, and
telescopic joint.
[0141] It is a sixth object of the present invention to provide an
exploration method in drilled well with capsule for conditioning
components comprising the following steps:
[0142] a. inserting a coating capsule (IT) inside a drilled
well;
[0143] b. inserting an lifting assembly (PA) inside the coating
capsule (IT).
[0144] In one embodiment, the steps of the method occur
independently from each other.
[0145] Because the system uses an electric pump, it is necessary
the lowering an electric power cable joint to the production
column, fastened to the same by clamps, to provide electrical
energy for engines moving the centrifugal pumps.
[0146] All this submerged electric pump assembly is inside the
coating water-tight capsule, isolating the formation produced
fluids from the rest of the well, called annular space (space
formed between the production coating and the production column+BCS
capsule). The higher the flow produced, the greater the power
required by the engines, which will have larger external diameters
and the capsules that will house them will also need to be
larger.
[0147] In workovers operations for exchanging the submerged
electric pump assemblies, the non-solid capsule remains in the
well, allowing any object that falls into the well to be easily
recovered (since they will be inside the capsule). This very
important aspect prevents such objects from falling above the
"gravel packer" which would result in the need for a special
complex and risky "fishing" operation, which could lead to the loss
of the well.
[0148] According to the stops of the submerged electric pump
assemblies caused by damage, the option to continue producing the
well using gas-lift can be used with the gas injected by the
annulus entering the gas-lift mandrel housing to reach the gas-lift
mandrel. The gas-lift mandrel housing can direct the flow into the
mandrel or into the column, depending on the flow of pumped fluids.
That is, the system of the present invention is selective regarding
the pumped flows and the types of fluids: whether gas or liquid.
This is critical for preserving high-speed gas-lift valves
generated by fluids pumped into the annular space during
damping.
[0149] Advantages presented by the present invention comprise: fast
assembly and lowering of the capsules; fast assembly of pumping
assemblies; possibility of pump exchanges without the need to
remove the capsules; possibility to eliminate maneuvers of balances
and dummy run; elimination or minimization of the possibility that
"fishes" inside the well generate complex and risky "fisheries"
with great financial losses and even loss of well; possibility of
adding recoverable Mandrel of Gas Lift (MGL) with the BCS
assemblies; possibility to perform TFR with BCS and superior
completion only by changing the pumps used in each operation
without the need to remove the capsule.
[0150] It is a seventh object of the present invention to provide a
telescopic joint for adjusting the mounting distance between
components of an exploration system of drilled well comprising
linear extension means for connecting components of an lifting
assembly (PA) and/or for adjusting the total length of lifting
assembly (PA).
[0151] In one embodiment, the telescopic joint comprises means for
passing the functional devices through the joint; and means for
regulating the total length of the joint.
[0152] In one embodiment, functional devices comprise hydraulic
lines and/or electric cables, for remote feeding of components of
the system components of exploration of drilled well.
[0153] In one embodiment, functional devices comprise piping of
chemicals able to inject them in predefined regions of the drilled
well, to ease the fluid extraction/lifting process.
[0154] In one embodiment, the means for length regulation comprise
expandable hydraulic units.
[0155] In one embodiment, the joint comprises: outer liner (32);
upper concentric sleeve (33); outer flow tube (34); cable (35) for
pressure and temperature sensor; expandable hydraulic unit (36);
sliding sleeve (37); inner liner (38); inner flow tube (39); lower
concentric sleeve (40); driving line (41); and mechanical lock
(42).
[0156] In one embodiment, the present invention provides a process
for extracting petroleum using a telescopic joint as previously
defined.
[0157] The present invention has the following advantages: enable
the use of smart completions of multiple zones; reduce welding
times in workovers for exchanging sets of joint BCS with smart
completion; and allow completions with hydraulic valves remotely
controlled.
[0158] It is an eighth object of the present invention to provide
an isolating valve for exploration system of drilled well
comprising opening and closing drive through pressure control
applied in the annular space (AE).
[0159] The present invention comprises a valve for closing and
isolating hydrocarbons-producer formations, being such valve
preferably controlled by hydraulic means.
[0160] In one embodiment, the valve for closing and isolating is
exclusively controlled by hydraulic means.
[0161] In one embodiment, the valve for closing and isolating
comprises a cylindrical wrap (54), lower connection flange (52),
flange holes (55), valve shell (56), shut-off valve body (46),
grooved cylindrical shaft (46S), spiral reservoir (53), linear
actuator (43) and upper connection flange (51).
[0162] In one embodiment, the valve for closing and isolating
comprises in the same body holes offset 90 degrees such that such
holes alternate the valve opening for production column and the
closing for annular space.
[0163] In one embodiment, the valve for closing and isolating is
arranged above the lower completion allowing the reverse
circulation for cleaning the column without flow rate limit.
[0164] In one embodiment of the present invention, a method for
closing and isolating hydrocarbons-producer formations comprises at
least one step wherein a shut-off valve is controlled by hydraulic
means.
[0165] In a ninth object, the present invention has a method for
closing and isolating formations in drilled well comprising at
least one step wherein a shut-off valve (CV) is controlled by
hydraulic means.
[0166] In one embodiment, the method comprises an additional step
of reverse circulation for column cleaning without flow rate
limit.
[0167] In one embodiment, the method comprises a step of positions
switching of the shut-off valve between the opening for production
column and the closing for annular space.
[0168] The valve of the present invention has several advantages
as: allow closing the well and isolating the formation by hydraulic
action in the annular space of the wells; eliminate the control
line for its drive and control, making the wellhead equipments
project simpler; allow several operations of reverse circulations
with high flow rates, improving wells' cleaning; allow performing
TFR (Formation test for coated well) with bottom closing; simplify
the control mechanism increasing the reliability of it (there is no
index system); and allow the variation in the opening area to the
flow.
[0169] It is a tenth object of the present invention to provide a
system for controlling the isolating valve driving for exploration
system of drilled well comprising opening and closing drive
through: [0170] a. pressure control applied in the annular space
(AE); and [0171] b. pressure and/or drag resulting from kinetic
energy imposed to high fluid.
[0172] In one embodiment, illustrated in FIGS. 21.1, 21.2 and 21.3,
the valve positions are indicated during a flow (FIG. 21.1) during
a production stop (FIG. 21.2) and in the well reopening (FIG. 21.3)
wherein it becomes necessary to annular space pressurization. By
doing so, the fluid will take two paths. The first will pressurize
acting pistons that will decline and rotate the sprockets, joint to
the actuator cylinder, through two small racks. Turning the
actuator cylinder counter-clockwise will let the well open. The
second path taken by the annular fluid will have to overcome the
opposite effort in the differential piston exerted by the pressure
in the column. As the area of the differential piston is much
larger in the area that acts on the pressure in the column, in
order to obtain the balance of forces, high pressure must be
applied to the opposite side where the annular pressure, whose area
is much smaller, is applied. By pushing the differential piston,
the path will be closed to the pressures coming from the column and
released to those applied in the annular.
[0173] Thus, the hydraulic actuator is pushed to the right, closing
the path of the fluid that was pumped to power the actuator piston,
responsible for opening the valve. The pressure will be "mopped"
until the hydraulic actuator is again pushed to the left, the
drainage hole coinciding with the access channel to the actuator
pistons. When this occurs, all "mopped" pressure will drain into
the column and the nitrogen compressed into the nitrogen spiral
reservoir by pushing up the actuator pistons that will force the
rotation of the gear clockwise closing the well. It should be noted
that the "trigger" of the bottom closure process is the mechanical
actuator driven whenever the flow of the well is interrupted. This
occurs because when the flow occurs, the upstream.times.downstream
pressure differentials generated in the choke tube can push it
upwards, overcoming the force of a spring. At this time, another
spring pushes the mechanical actuator to the right, closing the
path for pressures from the column, keeping the hydraulic actuator
in its position of closing the drainage hole. By interrupting the
flow, for any reason, the upstream.times.downstream pressures
acting on the choke tube become equalized and the spring is able to
push the choke tube downwards, which will consequently force the
hydraulic and mechanical actuator assembly to the left, causing the
drainage hole to return to the position coinciding with the access
channel to the actuating pistons which in turn will immediately
release the pressure that had been "mopped" in the spiral nitrogen
reservoir.
[0174] In an embodiment, the smart completion and gradual opening
and closing valve, illustrated in FIGS. 22.1, 22.2, 22.3, where the
drawings indicate the valve positions totally open (22.1),
partially open (22.2) and totally closed (22.3). For using the
innovative actuator cylinder concept in smart completion valves, it
was necessary to divide the system into 2 or 4 smaller actuator
cylinders positioned laterally to the axis of the production column
so that the actuation of these, closing or restricting a zone flow,
did not affect the production of the others. It is highlighted
that, in a smart completion, the objective is to produce or inject
in several zones together with independent control for each
interval. Each interval will produce or inject through its
respective valve, the flow of which will flow or enter laterally
from the annular space into the column where it will mix with the
production of the other zones. The amount of teeth in the rack will
determine the size of the opening in the actuator cylinder per
pressure x depressurization cycle. In this way, it is understood
that the opening and closing process is not continuous, but
stepped, although such steps can be formed by small increments.
[0175] It is a eleventh object of the present invention to provide
a selecting valve of operation fluid comprising a selecting valve
body (65) provided with two passages in order to segregate the flow
of one primary fluid of the flow of one secondary fluid, being the
primary fluid provided with at least a property different from the
secondary fluid.
[0176] It is a twelfth object of the present invention to provide
the use of selecting valve for controlling operation and
maintenance of gas lift equipment where the selecting valve is as
defined in this description and is intended to an exploration
system of drilled well.
[0177] Oil reservoirs need, at some point in their productive
lives, a method to supplement the energy (pressure) of hydrocarbon
bearing rocks. The preferred artificial lifting methods in the
underwater completions and/or high discharge wells are: gas lift
and/or BCS.
[0178] Gas lift mandrels are devices with a side pocket, eccentric
relative to the center of the production column, where valves will
be housed which will allow one-way flow of the annular space (space
between the coating and the production column) into the production
column. Typically, these mandrels, with their respective valves,
are positioned as deeply as possible inside the wells. These valves
allow the gas passage being injected into the annular space to
gasify the produced fluids, reducing the density of the mixture and
allowing the pressure energy of the reservoir rocks to be enough to
cause the flow to reach the production facilities. The mandrel
itself has only holes that, without its respective valve housed in
the pocket, would pass in both directions "column.times.annular".
However, with the valve installed, this path is only in the
"annular.times.column" direction.
[0179] Because it is a point of communication between the annular
and the production column, it is there that the circulation of
completion fluids occurs when it is necessary to remove the oil
from the columns and to damp the wells. When there is circulation
without a probe being on the well, this may mean that the gas-lift
valve is housed in the pocket of its respective mandrel and in this
case the flows of circulated fluids should be greatly reduced so as
not to damage these valves. During a workover, if this valve can be
removed with slickline, it will be possible to increase the flow
rate sufficiently, and almost without restrictions, for an
efficient cleaning of the column.
[0180] It should be noted that the damage caused in a gas lift
valve has the potential to result in probe workover (resulting in
significant production costs). Mainly, if the damage is in the
"check valve" (valve that allows one way flow "annular x column")
of the valve. In this case, the produced fluids fill the annular
space and the column is no longer a safety barrier.
[0181] The device, hereinafter referred to as the selective valve,
proposes to be an advantageous alternative to the current gas lift
mandrels, allowing liquid and gas flows at the maximum possible
flow rates, reducing probe times and providing more effective
column cleaning during workovers. This device is specially designed
to be positioned below BCS assemblies and can be used at any point
in the production column.
[0182] When the proposed device is used together with BCS
(Submersible Centrifugal Pumps) and positioned below them, it is
even possible to change the conventional gas lift mandrel (when
removing the "motor-pump" assemblies) without needing to remove the
selective valve.
[0183] The gas lift valve applied in the selective valve of the
present invention is provided with two passages being them one
primary hole (19) and one secondary hole (20), in order to
segregate the flow of one primary fluid of the flow of one
secondary fluid, being the primary fluid provided with at least a
property different from the secondary fluid, additionally the valve
is composed of the following items: [0184] valve body (65); [0185]
sealing piston (66) comprising at least one primary actuation
mechanism (67); [0186] primary hole (19); [0187] flow tube (68)
comprising at least one secondary actuation mean (69); and [0188]
secondary hole (20);
[0189] wherein: [0190] primary (19) and secondary (20) holes
transversally arranged in the valve body (65); [0191] the sealing
piston (66) and the flow tube (68) longitudinally arranged inside
the valve body (65); [0192] the sealing piston (66) aligned with
the flow tube (68) and arranged in the lower end (71) thereof.
[0193] The distinction property of one primary fluid from one
secondary fluid is selected from: compressibility, viscosity,
density, pressure or a combination thereof. Being preferably the
gas lift valve applied in the selective valve (SV) of the present
invention positioned below the set of submerged centrifugal pumps
(BCS), and the lower end of the flow tube (71) geometrically
compatible with the sealing piston head (66).
[0194] Regarding the primary actuation mechanism (67) and secondary
actuation mechanism (69), preferably such actuation means are each
one a spring, but not limited to it. However, the secondary
actuation mechanism (69) spring comprises elastic constant higher
than elastic constant of the primary actuation mechanism spring
(67).
[0195] The selective mandrel is composed of the following items:
[0196] Tube with perforation (73); [0197] Selective valve, as
defined above; [0198] Centralizer with upper elastomer; [0199]
Conventional gas-lift mandrel (21); and [0200] Centralizer with
lower elastomer.
[0201] It is a thirteenth object of the present invention to
provide an electro-hydraulic (EP) connector for exploration system
of drilled well comprising:
[0202] a. at least one internal assembly (22); and
[0203] b. at least one external assembly (23)
[0204] wherein: [0205] the internal assembly (22) is able to couple
to the external assembly (23); [0206] the internal assembly (22)
has electrical connections (87 and 80) and hydraulic connections
(76); [0207] the external assembly has electrical connections (87
and 80) and hydraulic connections (76); and [0208] the connections
are allocated in order to coincide when the coupling occurs.
[0209] It is a fourteenth object of the present invention to
provide an electric-hydraulic expansion joint comprising:
[0210] a. tubular lower component provided with: [0211] thread in
the lower part for connecting into electro-hydraulic connector;
[0212] sealing in the upper part between the lower component and
the inner cylinder; [0213] hexagonal lock system able to prevent
the internal column turn and to allow the torque transmission
between lower and upper component; [0214] lock system for column
decline with the extension fixed in the totally closed position;
[0215] external ring (upper and lower) of external hydraulic and
electric lines alignment; [0216] bars for filling the empty space
between external hydraulic and electric lines; and [0217]
protection liner of internal hydraulic and electric lines,
[0218] b. tubular upper component provided with: [0219] cylindrical
top (95) with thread in the center for inner sliding tube; [0220]
thread for connection into the production column (96); and [0221]
peripheral threads (97) for connecting hydraulic and electric
lines.
[0222] It is a fifteenth and last object of the present invention
is to provide an exploration method in drilled well using an
electro-hydraulic connector and/or electric-hydraulic joint as
defined in this description.
[0223] In one embodiment, electric connectors (80, 87) have
protection mechanism (78, 85).
[0224] In one embodiment, protection mechanisms (78, 85) are driven
by mechanic elastic device (79, 86).
[0225] In one embodiment, hydraulic connectors have sealing (89) in
order to ensure complete water-tightness thereof.
[0226] The present invention has also the following advantages:
enable the use of smart completions of multiple zones; reduce
welding times in workovers for exchanging sets of joint BCS with
smart completion; and allow completions with hydraulic valves
remotely controlled.
[0227] For purposes of the present invention, the term "annular
region" consists of the region of clearance between the inner wall
of the removable capsule and the elevation assembly or the pumping
duct, as mounting arrangement. The annular region generally
comprises the region between the main duct, whereby the well
produces fluids, and the coating of the said well.
[0228] All objects of the present invention, in one embodiment, are
intended for the exploration of drilled wells for
extraction/elevation of hydrocarbons, of which may be listed:
petroleum; gas; bitumen; or any other equivalent, of commercial
interest for processing and/or application in several areas of the
industry.
EXAMPLE 1
Preferred embodiment
[0229] The examples here shown aim to exemplify only one of the
several manner to perform the invention, however not limiting the
scope thereof.
[0230] According to FIG. 1, there is one first main tube (MT1)
having packer seal bore (11) in its lower portion. Inside the said
first main tube (MT1) it is associated a first inner capsule (IT1)
provided with gas lift mandrel (21), isolating valve (28) and
primary coupling (29). The first inner capsule (IT1) also has an
upper polished region (15A) for seating the packer feedthru
(3).
[0231] Internally associated to the first inner capsule (IT1), it
is seen the first lifting assembly (PA1) provided with flapper
valve (2), fixation clamp (5), packer feedthru (3), pumping device
(4), pressure sensor PDG (8), injection valve (30) and secondary
coupling (12). When inserted into the first main tube (MT1), the
primary coupling (29) present in the first inner capsule (IT1) is
coupled into the packer seal bore (11) and seals fluids leakage
through an elastomeric sealing (31) present in the said primary
coupling (29).
[0232] When associating the first lifting assembly (PA1) to the
first inner capsule (IT1), the secondary coupling (12) is
responsible for opening the isolating valve (28) present in the
first inner capsule (IT1).
[0233] FIGS. 4.1 and 4.2 illustrate a sequence of removal of the
first lifting assembly (PA1) for wells of a single producing zone
(7). FIG. 4.1 illustrates the first lifting assembly (PA1) inserted
into the first inner capsule (IT1) that, in turn, is inserted into
the first main tube (MT1). In this position, the primary coupling
(29) present in the first inner capsule (IT1) is inserted into the
packer seal bore (11) present in the first main tube (MT1). In
turn, secondary coupling (12) is inserted into the isolating valve
(28), in order to keep it opened, allowing fluids production from
the drilled well.
[0234] FIG. 5 illustrates the complete mount of the lower part of a
production column (1) for well with more than one producing zone
(7), the known completions of multiple producing zones. It is noted
the presence of flapper valve (2) preventing fluids return
downstream thereof, fixation clamp (5), and packer feedthru (3)
responsible for sealing and seating the second lifting assembly
(PA2) inside the second inner capsule (IT). The pumping device (4)
is located below the packer feedthru (3). The locator feedthru (6)
are responsible for isolating several producing zones that may be
met by the present invention. In image 5, the upper locator
feedthru (6A) separates the first producing zone (7A) from the
upper region, where the pumping device (4) is located. A pressure
sensor PDG (8) and a smart valve (9) are previewed to imply in the
well operation, according to external commands, or pre-scheduled.
Lower down, its is found the lower locator feedthru (6B)
segregating a second producing zone (7B) and, then as in the first
producing zone (7A), the said second producing zone (7B) has
pressure sensor PDG (8) and smart valve (9), besides a handling
tool (10). Still in image 5, there is the packer seal bore (11)
responsible for housing the secondary coupling (12). Finally, it is
seen in the FIG. 5, inner valves (13) present in the first
producing zone (7A) and in the second producing zone (7B), such
that to allow the produced fluids in the said zones to permeate the
inner part of the column through screwed holes (14), also present
in both producing zones (7A and 7B). Inner valves (13) will be
detailed along the description. In this image, it is shown how to
apply the knowledge of using a capsule to have the submerged
centrifugal pumping assembly in completions of multiple producing
zones.
[0235] FIGS. 6A and 6B detail mechanisms inside the production
column (1) for multiple producing zones, in order to promote a
better view thereof. Thus, FIG. 6A details the flapper valve (2)
preventing the return of the produced fluids and those already
pumped downstream thereof, the fixation clamp (5) fixing electric
cables and hydraulic lines, among others, the packer feedthru (3)
centralizing and fixing the second lifting assembly (PA2) inside
the second inner capsule (IT2) and the pumping device (4) supplying
energy to the fluid that is being produced from the drilled well,
in order to pump it and remove it, being the said pumping device
(4) located below the packer feedthru (3). FIG. 6B details the
upper locator feedthru (6A) separating the first producing zone
(7A), where it is also noted a pressure sensor PDG (8) and a smart
valve (9) arranged for implying in the well operation, according to
external commands, or pre-scheduled. Below it is noted the lower
locator feedthru (6B) segregating a second producing zone (7B) also
with pressure sensor PDG (8) and smart valve (9).
[0236] Also in FIG. 6B, it is clear the view of the handling tool
(10) responsible for opening inner valves (13) present in the first
producing zone (7A), and in the second producing zone (7B), in
order to allow the produced fluids in the said zones to permeate
the column inner part through screwed holes (14), also present in
both producing zones (7A and 7B). In this image, it is clear that
inner valves (13) are open and screwed holes (14) allow fluids
entering until the second lifting assembly (PA2). Finally, it is
noted the packer seal bore (11) having the secondary coupling
(12).
[0237] FIG. 7 illustrates the second lifting assembly (PA2), which
may be easily removed from inside the second inner capsule (IT2),
in order to allow the pumping device (4) exchange without the need
of onerous workovers. FIG. 8 discloses the second inner capsule
(IT2) with upper polished region (15A) for seating the packer
feedthru (3), besides the inner valves (13) allowing the produced
fluids passage through screwed holes (14). The lower polished
regions (15B) are useful for correct seating of the upper and lower
locator feddtrhu (6A and 6B). The secondary coupling (12) ends the
second inner capsule (IT2). The said second inner capsule (IT2) is
a tube aiming to have the second lifting assembly (PA2), in order
to avoid possible parts to loose from the said second lifting
assembly (PA2) when removing this. When having the parts that
possibly come to detach from the second lifting assembly (PA2), the
second inner capsule (IT2) avoids the parts to go to the bottom of
the well and generate onerous and complex fisheries. The second
inner capsule (IT2) may be easily removed, clean and replaced in
the second main tube (MT3). Finally, image 9 illustrates the second
main tube (MT2), which is the coating tube of the production column
(1). The said second main tube (MT2) is responsible for having
screwed holes (14), allowing the produced fluids to pass to the
inner part of the production column. Also about the second main
tube (MT2), the same has packer seal bore (11) in its lower part so
the well may be closed when it is not with the second inner capsule
(IT2) dully positioned.
[0238] FIGS. 10.1, 10.2 and 10.3, illustrate how inner valves (13)
are operated by the handling tool (10). FIGS. 10.1, 10.2 and 10.3
were arranged with a representation in plant (arranged in the lower
part of the in lifting views) of the inner part of the handling
tool (10) and of the inner valve (13), in each one of the
situations depicted. The vector (16) indicates the handling tool
(10) displacement that, according to FIG. 10.1, is in a position
where the handling tool (10E) splines are conflicting with the
inner valve (13E) splines, being then, the movement (vector 16)
imposed by the handling tool (10) is transferred to the inner valve
(13), that also starts to displace in the vector direction (16).
FIG. 10.2 depicts this movement in one intermediate instant, also
with handling tool (10E) splines displaced from inner valve (13E)
splines. Finally, image 10.3 depicts one instant that, through the
handling tool (10) turn, the handling tool splines (10E) are
aligned with the inner valve (13E) splines, such that the said
handling tool (10) keeps its movement in the vector direction (16),
however the inner valve (13), provided with the inner valve splines
(13E), keeps stopped. Also, in image 10.3, it is realized that
screwed holes (14) were opened, allowing the fluids to enter from
the producing upper zone (7).
[0239] FIG. 11 illustrates the pumping device (4), with one
electric engine (4A) coupled to a submerged centrifugal pump (4B).
This set is known by those skilled in the art as set of BCS, or set
of submerged centrifugal pump.
[0240] According to FIG. 12, the electro-hydraulic telescopic joint
(TJ) of the present invention is composed of: outer liner (32),
upper concentric sleeve (33), outer flow tube (34), cables (35),
expandable hydraulic unit (36), sliding sleeve (37), inner liner
(38), inner flow tube (39), lower concentric sleeve (40) and
driving line (41) for driving the mechanical lock (42).
[0241] The mounting of the electro-hydraulic telescopic joint (TJ)
is made by associating between outer liner (32) and inner liner
(38). The upper concentric sleeve (33) has one central hole for
associating the outer flow tube (34) and several concentric smaller
holes where expandable hydraulic units (36) are associated. Through
the upper annular space (32A), in communication with the lower
annular space (38A) hydraulic flow is passed for driving valves and
chemicals for chemical injection mandrels. Expandable hydraulic
units (36) are coupled one in another, in order to achieve, when
totally open, a length greater than the total course of the
electro-hydraulic telescopic joint (TJ) totally open. This makes
necessary to avoid efforts transfer being for these units and for
outer liners (32) and inner liners (38). The cable (35) is mounted
in spiral way around the inner flow tube (39). Along the outer flow
tube (34) the cable (35) is attached, kept slightly pulled by the
sliding sleeve (37). The said sliding sleeve (37), when traveling
the inner flow tube (39) length, through contraction, or expansion
of the electro-hydraulic telescopic joint (TJ), causes the cable
(35) spirally arranged around the inner flow tube (39) to be
compacted, or extended, without damaging the said cable (35).
[0242] The set composing the named outer liner (32) is formed
basically by the expandable hydraulic units (36), outer flow tube
(34) and upper concentric sleeve (33). The said outer liner (32) is
associated to the inner liner (38) by coupling the outer flow tube
(34) to the inner flow tube (39) through the sliding sleeve (37).
Once associated to the outer flow tube (34), the sliding sleeve
(37) slides around the inner flow tube (39), promoting the
expansion and contraction of the electro-hydraulic telescopic joint
(TJ). Optionally, it is possible to add to the electro-hydraulic
telescopic joint (TJ) a mechanical lock (42) that, through the
driving line (41), allows the relative movement between the sliding
sleeve (37) and the inner flow tube (39). In a summarized manner,
it is highlighted that the mechanical lock (42) is used to lock or
not the electro-hydraulic telescopic joint (TJ).
[0243] FIGS. 13 and 14 illustrate one comparison of drilled wells
having production columns (1) and telescopic joint (TJ).
Specifically, FIG. 13 illustrates one well wherein the production
column is not equipped with telescopic joint (TJ), and FIG. 14
illustrates a production column (1) provided with the said
telescopic joint (TJ). An example of comparison of the application
for "Electro-Hydraulic Telescopic Joint (JTEH)" may be seen and
compared in FIGS. 13 and 14.
[0244] In FIG. 13, without the electro-hydraulic telescopic joint
(TJ), a whole lifting assembly (PA) is engaged in two points, which
are packer feedthru (3). As these elements normally are unfixed
from the production coatings by applying traction, two of these
elements duplicate necessary efforts for "unseating" of these
devices, what is not normally achieved by overcoming the
capabilities of the production tubes. Thus, special operations
significantly would be necessary to separate the lifting assembly
part (PA) from the production column (1) remaining.
[0245] In FIG. 14, the electro-hydraulic telescopic joint (TJ)
allows the lifting assembly (PA) to be emerged in the surface
without the completion remaining is removed.
[0246] FIG. 15 discloses an embodiment of the shut-off valve (CV),
where it is possible to note the linear actuator (43), responsible
for opening and closing of the production column and, inversely, of
the annular space (AE). Together with linear actuator (43) there is
a rack (44) arranged in contact with a gear (45) that, when
displaced, provokes the shut-off valve body (46) turn.
[0247] Also in FIG. 15, it is possible to note the presence of a
spiral reservoir (53) connected to the linear actuator (43), the
said spiral reservoir (53) is detailed further on.
[0248] Gears (45) are constructed with the ratchet system (47),
such that the shut-off valve body (46) rotates only in one
direction.
[0249] FIG. 16 illustrates a cross side view of the system of gear
(45) and rack (44), where it is possible to note the arrangement of
the ratchet system (47), this system formed by return elastic
elements (48) pressing projections at angle (49) against the gear
inner part (45). The said gear inner part (45) has cavities (50)
for accommodating projections at angle (49). In this image, the
linear actuator (43) and rack (44) operation is apparent. Also in
FIG. 16, it is possible to note the upper connection flange (51)
and the lower connection flange (52), both responsible for
associating the shut-off valve (CV) wherever it is necessary.
[0250] Image 17 highlights the linear actuator (43) operation
associated to the rack (44) operating the ratchet system (47)
formed by the gear (45) having cavities (50), return elastic
elements (48) and projections at angle (49).
[0251] In image 18, an exploded view depicts the shut-off valve
(CV) components. When moving the linear actuators (43), associated
to racks (44), in the ascending or descending direction, will
result in the gear rotation (45) in the clockwise or
counter-clockwise direction. In case of descending movement by
linear actuators (43), projections at angle (49), forced by the
return elastic elements (48) against the cavities (50) present in
the gears (45), will force the grooved cylindrical shaft (46S)
rotation, being the said grooved cylindrical shaft (46S) joint to
the shut-off valve body (46), the latter rotates, causing to open
or close of the drilled well and, in , causing to open or close the
annular space (AE). On the other hand, when actuated by the racks
(44) in ascending direction, gears (45) rotate in the
counter-clockwise direction without transmitting the rotation for
grooved cylindrical shaft (46S) due to the fact that the
projections at angle (49) and return elastic elements (48) are
compressed inside the cavities (50) of the grooved cylindrical
shaft (46S), allowing the free rotation of the gears wheels (45).
That is, only during descending movements of the linear actuator
(43) it is allowed to transmit the rotation for shut-off valve body
(46) and, thus, drive the shut-off valve (CV) opening and
closing.
[0252] During rises, by depressurizing the well annular space (AE),
the spiral reservoir (53), operating as spring, withdraws the
linear actuators (43) back to above not allowing the shut-off valve
body (46) to move. This fact is important, since it is not
necessary to keep the annular space (AE) pressurized all the time
to allow the valve maintenance in a certain position. Therefore, a
complete cycle of pressurization and depressurization is necessary
to establish a certain position in the valve. It is highlighted
that this device allows its opening variation. With that, it is
possible to operate it out of the open and closed positions,
only.
[0253] Also in FIG. 18, it is possible to note a cylindrical wrap
(54), associated to the upper connection flange (51) and to the
lower connection flange (52), in order to have all the set forming
the shut-off valve (CV), ending the mount. The said shut-off valve
(CV) mount is simple due to the tiny amount of components. The
lower connection flange (52) mounting is started. This component
will be leaked axially by one greater hole (57), where produced
fluids will pass and, concentrically, by one or more smaller flange
holes (55) where the fluid of completion will pass resulting from
the annular space (AE) during reverse circulation operations. Such
flange holes (55) will be provided from retention valves to allow
the flow in single direction of the annular space (AE) to the
column. Over the lower connection flange (52), the valve shell (56)
is mounted. The valve shell (56) has shell holes (57) that, in the
valve shell (56) mounting over the lower connection flange (52),
they must be aligned with the flange holes (55). Finally, the
shut-off valve body (46) is inserted into the valve shell (56),
forming the main mechanism of the shut-off valve (CV).
[0254] The seating system between the parts was implemented in the
metal.times.metal modality, without limiting to them. It is
highlighted that the shut-off valve body (46) shall also have side
holes perpendicular regarding the central hole, where the produced
fluids of the drilled well pass through, but without coinciding in
order to allow reverse circulations with the production hole
closed, preventing the well to absorb fluids. The spiral reservoir
(53) is mounted with linear actuators (43) and upper connection
flange (51), over the cylindrical wrap (54).
[0255] Image 19 depicts ratchet system components (47), which are
responsible for causing the shut-off valve body (46) rotation in a
single direction. In this image, it is possible to note the grooved
cylindrical shaft (46S), the gear (45), the set of projections at
angle (49) and return elastic elements (48) and, finally, the
ratchet system mounting (47).
[0256] Image 20 illustrates, in plant, the main mechanisms of the
shut-off valve (CV). It is possible to note the presence of
cylindrical wrap (54) having the valve shell (56), the shut-off
valve body (46), the linear actuators (43) and gears (45).
[0257] FIGS. 21.1, 21.2, 21.3 and 22 disclose an embodiment for a
system for controlling valve (6) associated to shut-off valve (CV),
such that to provide control thereof.
[0258] FIG. 21.1 refers to shut-off valve (CV) during a flow being
produced from the drilled well. FIG. 21.2 illustrates the shut-off
valve (CV) during a production stop and, finally, image 21.3
illustrates the shut-off valve (CV) in the well reopening wherein
it becomes necessary to pressurize the annular space.
[0259] In FIG. 21.1, the control mechanism (CM) is not driven by
the inner sleeve (17), since there is a flow being produced and,
therefore, keeping the said inner sleeve (17) in an upper position.
In this position, the mechanic actuator (58) is extended and the
drainage hole (60) does not allow the fluid to pass through the
primary duct (63). Such primary duct (63), connects the production
main hole to the linear actuator (43), such that the fluid
pressure, which is being produced, is the same acting over the
linear actuator (43). In this position, the differential piston
(61) does not allow the pressure of the annular space (AE) to be
detected by the hydraulic actuator (59), such that the pressure
performed over the said hydraulic actuator (59) is the pressure
resulting from the primary duct (63), which is in the same pressure
of the fluids being produced from the drilled well. It is also
previewed an anti-return valve, or one way valve (V) arranged in
the communication between the annular space (AE) and the shut-off
valve (CV) internal part.
[0260] According to image 21.2, when the flow is stopped, the first
actuation mean (18) displaces the inner sleeve (17) against the
mechanic actuator (58), such that this allows the fluid, being
produced, pressure to pass towards the hydraulic actuator (59),
displacing it to the left. Provided with drainage hole (60), the
hydraulic actuator (59) connects the upper and lower portions of
the primary duct (63), such that linear actuator (43) is displaced
in the ascending direction. In this position, the differential
piston (61) is found in the arrangement presented in FIG. 21.1,
since the annular space (AE) was not pressurized, necessary
pre-requirement so the said differential piston (61) is displaced.
Also in this image, it can highlight that the secondary elastic
element (60), associated to the mechanic actuator (58) is
compressed.
[0261] FIG. 21.3 illustrates one instant wherein the annular space
(AE) was pressurized and displaced the differential piston (61) to
the right, what opened the passage for the annular space fluid to
fill a secondary duct (64), being the said secondary duct (64)
communicating with the left side of the hydraulic actuator (59),
such that the said hydraulic actuator (59), under the annular space
(AE) pressure displaced to the right, so the drainage hole (60)
cuts the communication between the upper and lower part of the
primary duct (63). This causes the pressure of the annular space
(AE), directly connected to the linear actuator (43), to displace
the said linear actuator (43), forcing the ratchet system (47)
rotation, opening the shut-off valve (CV). Accordingly, the
pressure actuation of the annular space (AE) over the said linear
actuator (43) was clear.
[0262] The amount of teeth in the rack (44) will determine the
opening size in the shut-off valve body (46) by cycle of pressure x
depressurization. Thus, it is understood that the opening and
closing process is not continuous, but stepped, also such stepping
may be formed by small increments.
[0263] FIG. 22.1 illustrates the shut-off valve (CV) with shut-off
valve body (46) controlling only the communication between the
annular space (AE) and the duct inside the valve conducting the
produced fluids from the drilled well, according to the present
invention teachings. More specifically, FIG. 22.1 discloses a
second embodiment of the shut-off valve (CV) in a position allowing
the communication between the annular space (AE) and the duct
inside the valve.
[0264] FIG. 22.2 illustrates one instant wherein, by acting the
control fluids in the linear actuator (43), the rack (44) is
displaced, inducing the gear (45) to rotate, causing the shut-off
valve body (46) to assume an intermediate position.
[0265] FIG. 22.3 illustrates one instant where the shut-off valve
body (46) is in the blocking position of the connection between
annular space (AE) and the production column internal part. By
acting the linear actuator (43), the rack (44) displaced the gear
(45) that induced the shut-off valve body (46) to rotate. It is
important to highlight that shut-off valve (CV) was described using
a linear actuator (43) for displacing its moving parts, so those
skilled in the art will value this knowledge and will know to apply
other rotating options as the hydraulic engines, electric engines,
among other examples.
[0266] Continuing with the completion system now proposed, FIG. 23
shows an embodiment of the selective valve (SV) of the present
invention, having its elements indicated: selecting valve body
(65), sealing piston (66) comprising primary actuation mechanism
(67), primary hole (19), flow tube (68) comprising secondary
actuation mechanism (69), lower end (71) and upper end (72),
secondary hole (20) and, finally, the fluid entry (70).
[0267] During the gas injection operations in the annular space of
the completion housed in the drilled well for performing the
gas-lift elevation, the said gas will enter into the selective
valve (SV) through the fluid entry (70) and the
"upstream.times.downstream" pressure differentials will reach the
force of the primary actuation mean (67), causing the sealing
piston (2) to lower and the gas to pass inside the production
column that fits this completion through primary hole (19), but the
viscosity of this first gas will not be able to generate enough
friction in the flow tube (68) walls enough to reach the secondary
actuation mean (69) force. The gas injected in the annular and
directed by the selective valve (SV) to the primary hole (19), will
enter into the gas-lift mandrel (21) and will gasify the production
column, reducing the density of the produced mixture, as currently
happens. It is necessary to highlight that the gas, as soon as
enter into the production column, remains inside the space formed
between upper locator feedthru (6A) and lower locator feedthru
(6B), promoting the proper sealing of the completion fluid, such
that the said fluid can enter only into the gas-lift mandrel (21),
reducing the density of the produced fluid.
[0268] FIG. 24 depicts an embodiment if the completion fluid is
liquid, where the Hydrodynamic friction caused in the flow tube
(68) walls will be big enough to generate a hydrodynamic drag of
the said flow tube (68) downwards, such that this reaches the force
of the secondary actuation mean (69) and compressing the "sealing
piston" (66) against the upper and lower faces thereof. This
promotes the two-way sealing. At this point, the opening present in
the upper end (72) will coincide to the secondary hole (20) and the
fluid will enter into the production column through the said
secondary hole (20).
[0269] FIG. 25 illustrates the selective valve (SV) of the present
invention assembled in a completion for wells, where it is possible
to note the paths the completion fluid can take after the selective
valve (SV). When diverting the path inside the gas-lift mandrel
(21) and enter by the perforation (73) arranged in the lifting main
tube of the completion, the completion fluid does not pass inside
the gas-lift mandrel (21), in a way to preserve it, once gas-lift
mandrels (21) do not support higher viscosities fluids (water, oil,
chemicals, etc.). Other reason for using the selective valve (SV)
is the fact of allowing flow rates of pumped liquids to be big
enough to promote effective cleaning of the production column,
preserving the integrity of the gas-lift mandrels (21) installed in
the production column of the completion now proposed by the present
invention.
[0270] Figures from 26 to 28 disclose an electro-hydraulic (EP)
connector for completion of drilled wells, where electro-hydraulic
connectors (EP) allow the disconnection of the production column
(1) part for maintenance, according to the present invention
teachings.
[0271] According to FIG. 26A, there is the external assembly (23)
of the electro-hydraulic (EP) connector where it is possible to
view the system of stamps (83) that are responsible for displacing
the lower electrical contacts protector (78) by compressing the
lower spring (79). The upper surface (84) is responsible for
displacing the upper electrical contacts protector (85) by
compressing the upper spring (86). In this figure, the upper spring
(86) is extended and the upper electrical contacts protector (85)
is positioned in order to provide the correct protection to outer
electric connectors (87). The electrical connection system also
occurs in a modular form, it is enough to add more electrical
connection assemblies.
[0272] In the FIG. 26B, it is possible to view the internal
assembly (22) of the electro-hydraulic (EP) connector in half cut.
The threaded element (74) is responsible for interconnecting the
internal assembly (22) of the electro-hydraulic (EP) connector to
the production column remaining. The polished region of the
connector (75) is responsible for ensuring the water-tightness of a
hydraulic connection (76) operating from one elastomeric elements
assembly for connector (77) (these elements are present in the
external assembly (23) of the electro-hydraulic (EP) connector)
ensuring the complete sealing of the said hydraulic connection
(76). The several hydraulic connections (76) occur in modular form,
being possible to increase the number of connecting points, or
reduce them. When the electro-hydraulic (EP) connector is decoupled
the lower electrical contacts protector (78) are in the extended
position through the force action performed by the lower spring
(79) in order to ensure proper protection of the internal electric
connectors (80). The internal tubular region (81) is responsible
for supporting well pressures and mechanical stresses of the
production column. Between the polished region of the connector
(75) and the internal tubular region (81) the region located for
allocating hydraulic and electric lines (82) such that the said
lines do not experience obstacles occurring inside the internal
tubular region (81).
[0273] According to FIG. 27, it can be seen the electro-hydraulic
(EP) connector components when it is in the "connected" position.
In this view, the internal assembly (22) is dully coupled to the
external assembly (23) and internal electric connectors (80) and
external electric connectors (87) are coupled, besides the
hydraulic connection (76) that is also dully connected. It is
possible to note that upper (86) and lower (79) springs are
compressed, internal and external electric connectors (80 and 87)
are aligned and dully connected and also hydraulic connectors (76)
are dully positioned in the polished region (75) in order to ensure
total water-tightness of the hydraulic lines.
[0274] FIGS. 28.1 and 28.2 depict a sequence of removal of pumping
device (4) by disconnecting the electro-hydraulic (EP) connector,
according to the present invention.
[0275] In FIG. 28.1 it can be noted the accessories of a lower
completion (88), generically represented. In this illustration, the
pumping device (4), generally formed by the engine and pump
assembly are represented in a merely illustrative manner and they
are connected to the lower completion (88) remainder through
electro-hydraulic (EP) connector of the present invention.
[0276] FIG. 28.2, as FIG. 28.1, illustrates a smart completion
provided with electro-hydraulic (EP) connector, with the difference
of being in the disconnected position. In this figure, it is easy
to view how the present invention will facilitate the decoupling
between the upper part having the pumping device (4) and lower
completion (88), for maintenance of the said pumping device (4),
formed by a BCS, for example. It is noticeable that the external
assembly (23) of the electro-hydraulic (EP) connector is associated
to the upper part that was removed from the smart completion and
the internal assembly (22) is associated to lower completion (88)
of the said smart completion.
[0277] FIG. 29 discloses a second embodiment for electro-hydraulic
telescopic joint (TJ) of the present invention. As illustrated,
this tool is composed of the following elements:
[0278] Tubular lower component with the following characteristics:
outer thread (27) for connecting into electro-hydraulic (EP)
connector, sealing (89) in the upper part between the outer tube
(24) and the inner tube (25), hexagonal lock system (26) to avoid
the inner column to rotate in false, performing torque transmission
between the lower and upper component, secondary lock system (90)
for column decline with the extension fixed totally in the closed
position, external ring upper (91) and external ring lower (92) for
aligning external hydraulic and electric lines, filling bars (93)
of empty space between the external hydraulic and electric lines
and, protection liner (94) of the internal hydraulic and electric
lines.
[0279] Tubular upper component with the following characteristics:
cylindrical top (95) with thread in the center to the inner tube
(25); thread for connecting into the production column (96) and
peripheral threads (97) for connecting hydraulic and electric
lines.
[0280] The components comprise the electro-hydraulic telescopic
joint (TJ) of the FIG. 29 are dully described below.
[0281] The inner tube (25) refers to a conventional expansion
joint. The inner tube (25) is composed of one conventional polished
cylinder sliding upwards and downwards, with sealing in the outer
liner top. The defined sliding course for balance will depend on
the constructive characteristics, but it can reach up to 6
meters.
[0282] The hexagonal lock (26) in the lower end of the inner
cylinder (25) avoids the independent rotation, impairing torque.
The protection liner (94) is responsible for connecting in the
lower part of the column. The sealing (89) system with the inner
cylinder (25) is located on the top. Internally, the protection
liner (94) is machined with shape to keep the cylinder alone in
case of rotation. The outer body is machined with grooves to
partially house the conduction hydraulic and electric lines.
[0283] The protection liner (94) refers to a cylinder coating the
outer lines, mechanically protecting against impacts on the lines
and keeping the lines positioned so they do not remain out of the
position. Hydraulic lines are miniatures of the main expansion
joint, with one outer tube and one inner tube. The outer fixed and
the inner sliding, with sealing of the outer tube top. The electric
lines are similar to hydraulic lines, but with electric conduction
purpose.
[0284] Those skilled in the art will appreciate the knowledge
presented herein and may reproduce the invention in the embodiments
presented and in other embodiments within the scope of the attached
claims.
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