U.S. patent application number 14/451159 was filed with the patent office on 2015-02-12 for steam injection and production completion system.
The applicant listed for this patent is SCHLUMBERGER TECHNOLOGY CORPORATION. Invention is credited to Bruce Boyle, Saikumar Mani, Adam Charles Vasper, David Verzwyvelt.
Application Number | 20150041129 14/451159 |
Document ID | / |
Family ID | 52447602 |
Filed Date | 2015-02-12 |
United States Patent
Application |
20150041129 |
Kind Code |
A1 |
Mani; Saikumar ; et
al. |
February 12, 2015 |
STEAM INJECTION AND PRODUCTION COMPLETION SYSTEM
Abstract
A completion for steam injection and production includes a
production tubing connected to the stinger, a downhole steam
generator (DSG) having a discharge connected to the production
tubing through an inverted Y-tool, a fuel supply tubing extending
between the DSG and a surface fuel supply and an air supply tubing
extending between the DSG and a surface fuel supply. The completion
can have an artificial lift device incorporated in the production
tubing.
Inventors: |
Mani; Saikumar; (Pearland,
TX) ; Boyle; Bruce; (Sugar Land, TX) ;
Verzwyvelt; David; (West Columbia, TX) ; Vasper; Adam
Charles; (Houston, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
SCHLUMBERGER TECHNOLOGY CORPORATION |
Sugar Land |
TX |
US |
|
|
Family ID: |
52447602 |
Appl. No.: |
14/451159 |
Filed: |
August 4, 2014 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
61863574 |
Aug 8, 2013 |
|
|
|
Current U.S.
Class: |
166/272.3 ;
166/57 |
Current CPC
Class: |
E21B 43/243 20130101;
E21B 43/24 20130101 |
Class at
Publication: |
166/272.3 ;
166/57 |
International
Class: |
E21B 43/24 20060101
E21B043/24 |
Claims
1. A method, comprising: generating steam at a downhole steam
generator (DSG) incorporated in an upper completion that is
deployed in a wellbore; injecting the steam into a formation
located below a lower completion deployed in the wellbore;
terminating steam generation; and producing formation fluid from
the formation through the upper completion after the terminating
steam generation.
2. The method of claim 1, wherein the upper completion is not
pulled out of the wellbore between the terminating steam generation
and the producing.
3. The method of claim 1, wherein the producing comprises operating
an artificial lift device incorporated in the upper completion.
4. The method of claim 1, wherein the producing comprises operating
an artificial lift device incorporated in the upper completion, the
artificial lift device comprising one selected from a pump, a gas
lift device, and a jet pump.
5. The method of claim 1, wherein: the upper completion is not
pulled out of the wellbore between the terminating steam generation
and the producing; and the producing comprises operating an
artificial lift device incorporated in the upper completion.
6. The method of claim 1, wherein the upper completion comprises: a
stinger landed in the lower completion; a production tubing
extending from the surface to the stinger; and a discharge of the
DSG connected to the production tubing through an inverted
Y-tool.
7. The method of claim 6, wherein the producing comprises operating
an artificial lift device incorporated in the upper completion.
8. The method of claim 6, comprising a one-way valve located in the
discharge of the DSG allowing one-way flow from the DSG.
9. The method of claim 1, wherein the upper completion comprises: a
stinger landed in the lower completion; a production tubing
extending from the surface to the stinger; a discharge of the DSG
connected to the production tubing through an inverted Y-tool; an
artificial lift device incorporated in the production tubing; a
fuel supply tubing extending between the DSG and a surface fuel
supply; and an air supply tubing extending between the DSG and a
surface air supply.
10. The method of claim 9, wherein: the upper completion is not
pulled out of the wellbore between the terminating steam generation
and the producing; and the producing comprises operating the
artificial lift device incorporated in the upper completion.
11. A completion for steam injection and production, the completion
comprising: a stinger; a production tubing connected to the
stinger; a downhole steam generator (DSG) having a discharge
connected to the production tubing through an inverted Y-tool; a
fuel supply tubing connected to the DSG; and an air supply tubing
connected to the DSG.
12. The completion of claim 11, comprising a water supply tubing
connected to the DSG.
13. The completion of claim 12, comprising: a jet pump incorporated
in the production tubing; and a control valve coupled between the
water supply tubing and the production tubing to actuate the jet
pump.
14. The completion of claim 11, comprising an artificial lift
device incorporated in the production tubing.
15. The completion of claim 11, comprising a one-way valve located
in the discharge of the DSG allowing one-way flow from the DSG.
16. A well system, comprising: a packer landed in a wellbore
between a formation and a surface; a stinger landed in the packer;
a production tubing connected to the stinger; a downhole steam
generator (DSG) having a discharge connected to the production
tubing through an inverted Y-tool; a fuel supply tubing extending
between the DSG and a surface fuel supply; an air supply tubing
extending between the DSG and a surface air supply; and a water
supply in communication with the DSG.
17. The well system of claim 16, comprising a water supply tubing
connected between the DSG and the water supply.
18. The well system of claim 16, comprising an artificial lift
device incorporated in the production tubing.
19. The well system of claim 16, comprising a one-way valve located
in the discharge of the DSG allowing one-way flow from the DSG.
20. The well system of claim 16, comprising: a one-way valve
located in the discharge of the DSG allowing one-way flow from the
DSG; and an artificial lift device incorporated in the production
tubing, the artificial lift device comprising one selected from a
pump, a gas lift device, and a jet pump.
Description
CROSS REFERENCE TO RELATED APPLICATIONS
[0001] This application claims the benefit of U.S. Provisional
Patent Application No. 61/863,574, filed Aug. 8, 2013 entitled
STEAM INJECTION AND PRODUCTION COMPLETION SYSTEM which is
incorporated herein by reference in its entirety.
BACKGROUND
[0002] This section provides background information to facilitate a
better understanding of the various aspects of the disclosure. It
should be understood that the statements in this section of this
document are to be read in this light, and not as admissions of
prior art.
[0003] Steam injection can be utilized to recover reservoir
hydrocarbons. For example, steam may be injected into a
subterranean formation through a first well and hydrocarbons
produced from adjacent wells. In huff and puff or cyclic
operations, steam is injected into a subterranean formation through
a wellbore and after a period of time formation fluids are produced
from the same well. In cyclic steam injection operations, a steam
injection completion may be installed in the wellbore for steam
injection and then pulled out of the wellbore when the steam
injection is terminated. A production completion is then run into
the wellbore when it is desired to place the well on
production.
SUMMARY
[0004] In accordance with some embodiments a completion for steam
injection and production includes a production tubing connected to
the stinger, a downhole steam generator (DSG) having a discharge
connected to the production tubing through an inverted Y-tool, a
fuel supply tubing extending between the DSG and a surface fuel
supply and an air supply tubing extending between the DSG and a
surface air supply. A method in accordance to some embodiments
includes generating steam at a downhole steam generator
incorporated in an upper completion that is deployed in a wellbore,
injecting the steam into a formation, terminating steam generation
and producing formation fluid through the upper completion. A well
system includes a sequential steam injection to production
completion installed in a wellbore.
[0005] The foregoing has outlined some of the features and
technical advantages in order that the detailed description of the
steam injection and production completion and methods that follows
may be better understood. Additional features and advantages will
be described hereinafter which form the subject of the claims of
the invention. This summary is not intended to identify key or
essential features of the claimed subject matter, nor is it
intended to be used as an aid in limiting the scope of claimed
subject matter.
BRIEF DESCRIPTION OF THE DRAWINGS
[0006] Embodiments of sequential steam injection and production
completions are described with reference to the following figures.
The same numbers are used throughout the figures to reference like
features and components. It is emphasized that, in accordance with
standard practice in the industry, various features are not
necessarily drawn to scale. In fact, the dimensions of various
features may be arbitrarily increased or reduced for clarity of
discussion.
[0007] FIG. 1 illustrates a well system in which embodiments of
sequential steam injection and production completions and method
can be utilized.
[0008] FIG. 2 illustrates a steam injection and production
completion having three tubing strings in accordance with one or
more embodiments.
[0009] FIG. 3 illustrates a steam injection and production
completion having four tubing strings in accordance with one or
more embodiments.
[0010] FIG. 4 illustrates a steam injection and production
completion having three tubing strings and an artificial lift
device in accordance with one or more embodiments.
[0011] FIGS. 5-7 illustrate steam injection and production
completions having four tubing strings and an artificial lift
device in accordance with one or more embodiments.
[0012] FIG. 8 is a diagram of sequential steam injection to
production method in accordance to one or more embodiments.
DETAILED DESCRIPTION
[0013] It is to be understood that the following disclosure
provides many different embodiments, or examples, for implementing
different features of various embodiments. Specific examples of
components and arrangements are described below to simplify the
disclosure. These are, of course, merely examples and are not
intended to be limiting. In addition, the disclosure may repeat
reference numerals and/or letters in the various examples. This
repetition is for the purpose of simplicity and clarity and does
not in itself dictate a relationship between the various
embodiments and/or configurations discussed.
[0014] As used herein, the terms "connect," "connection,"
"connected," "in connection with," and "connecting" are used to
mean "in direct connection with" or "in connection with via one or
more elements"; and the term "set" is used to mean "one element" or
"more than one element". Further, the terms "couple," "coupling,"
"coupled," "coupled together," and "coupled with" are used to mean
"directly coupled together" or "coupled together via one or more
elements". As used herein, the terms "up" and "down"; "upper" and
"lower"; "top" and "bottom"; and other like terms indicating
relative positions to a given point or element are utilized to more
clearly describe some elements. Commonly, these terms relate to a
reference point as the surface from which drilling operations are
initiated as being the top point and the total depth being the
lowest point, wherein the well (e.g., wellbore, borehole) is
vertical, horizontal or slanted relative to the surface.
[0015] FIG. 1 is an illustration of a well system 5 in which
sequential steam injection to production methods and completions,
generally denoted by the numeral 10, may be incorporated and
utilized. A wellbore 12 extends from a surface 14 to a formation 16
which is in communication with wellbore 12. At least a portion of
wellbore 12 may be lined with casing 18. Completion 10 includes a
lower completion 20 installed downhole and above formation 16 and
an upper completion 22 deployed below wellhead 24 and landed in
lower completion 20.
[0016] Lower completion 20 may include a packer 26 (i.e. production
packer) having a polished bore receptacle (PBR) 28 and a tail pipe
30 extending below packer 26. Lower completion may include an
isolation device 32 such as a valve, flow control device, or nipple
cooperative with a closure member 34. Closure member 34 is
illustrated in FIG. 1 as a flapper. For example, isolation device
32 may be mechanically operated between a closed and open position
for example by a mechanical shifting tool. In accordance with some
embodiments isolation device 32 may be for example a nipple and
closure member 34 may be a plug. For example the plugs may be
coiled tubing, wireline, or slickline deployed.
[0017] Upper sequential steam-production completion 22 includes a
downhole steam generator (DSG) 36 (e.g. combustor) that utilizes a
fuel such as natural gas or methane, and air to convert water to
steam downhole for injection into formation 16. Upper completion 22
may include a control line 38 extending from the surface to one or
more downhole devices. Control line 38 may be a cable, or
umbilical, having more than one conduit for transmitting power and
or signals. For example, control line 38 may include hydraulic
conduits, electrical conductors, optic fibers and the like. In FIG.
1, control line 38 is illustrated connecting a surface controller
40 with downhole steam generator 36. With additional reference to
FIGS. 4-7, control line 38 may be connected for example to sensors,
gauges, hydraulic and electrically operated flow control devices,
and artificial lift devices (e.g. pumps). Controller 40 may include
without limitation electronic circuits, processors, transmitters,
receivers and power supplies (i.e. hydraulic, electric), and valves
(valve manifolds).
[0018] Upper completion 22 in accordance to one or more embodiments
includes a production tubing 42 extending from the wellhead to
stinger 44 (seal assembly, stabber assembly) which is landed in PBR
28. Production tubing 42 may be a substantially continuous conduit
incorporating an inverted Y-tool 46 between the surface and stinger
44. Inverted Y-tool 46 includes a first inlet flow path or leg 45
that is continuous with a single outlet flow path or leg 49 and a
second inlet flow path or leg 47 that is combined into single
outlet flow path 49. Production tubing 42 is connected to first leg
45 of inverted Y-tool 46 and is connected to stinger 44 through
single leg 49.
[0019] Steam discharge 48 of DSG 36 is connected to stinger 44
through inverted Y-tool 46. Steam discharge 48 is connected to
second leg 47 of inverted Y-tool 46 and connected to stinger 44
through single leg 49. Inverted Y-tool 46 is illustrated located
adjacent to stinger 44 for the purpose of illustrating and
describing other features of the sequential steam-production
completion.
[0020] A valve 50 (e.g. check valve) is connected within steam
discharge 48 between DSG 36 and inverted Y-tool 46 to prevent back
flow into DSG 36 from below lower completion 20, e.g. formation
fluid, or from production tubing 42. Production tubing 42 may
include a barrier 52, for example a valve or retrievable plug, to
selectively close production tubing 42 for example to prevent steam
from being produced to the surface.
[0021] Upper completion 22 includes two tubing strings extending
from surface to provide fuel and air to DSG 36. For example, fuel
supply tubing 54 is deployed from wellhead 24 to DSG 36. Fuel
supply tubing 54 is connected to a fuel supply 56 (e.g. natural
gas, methane, hydrogen, etc.). Fuel source 56 may include a
compressor. Air tubing 58 is deployed from wellhead 24 to DSG 36.
Air tubing 58 is connected to an air source or supply 60 which may
include a compressor. With reference to FIGS. 1, 2 and 4, water 62
may be supplied from a water supply 64 into wellbore 12 (i.e.
annulus) and into inlet 65 of DSG 36. Water supply 64 may include
pumps. In accordance to some embodiments, for example as
illustrated in FIGS. 3 and 5-7, a water supply tubing 66 may
connect DSG 36 to the surface and water supply 64.
[0022] In accordance to one or more embodiments, upper completion
22 may include an artificial lift device 68 for example as
illustrated in FIGS. 4-7. Artificial lift device 68 may be without
limitation an electric submersible pump (ESP), positive
displacement pump, gas lift device (e.g. valve), or jet pump (i.e.
piston). For example, with reference to FIGS. 4 and 4, artificial
lift devices 68 are illustrated as pumps, such as electric
submersible pumps and positive displacement pumps.
[0023] FIG. 6 illustrates gas lift type (e.g. valve) of artificial
lift device 68 coupled for example to fuel supply tubing 54 through
a control valve 70. Gas (e.g. natural gas) from supply 56 (FIG. 1)
may be directed from fuel supply tubing 54 into gas lift device 68
to reduce the gravity of the formation fluid 72 in production
tubing 42 to aid production to the surface. FIG. 7 illustrates
sequential steam-production completion utilizing a jet pump type of
artificial lift device 68. For example, a power fluid (e.g. water)
from water supply tubing 66 can be directed for example via
controller 40 and control valve 70 to jet pump 68. Controller 40
may manipulate the application of power fluid to operate the jet
pump 68 stroke up and down in production tubing 42. In accordance
to some embodiments, DSG 36 (e.g. combustor) can be operated to
produce a hot effluent that is directed from discharge 48 to
artificial lift device 68. The hot effluent may reduce the
viscosity and gravity of the produced fluid. In some embodiments
the hot effluent is directed down through the discharge 48 without
need of an artificial lift device downhole. The hot effluent flows
downward from the DSG 36 through the Y-tool and into the production
tubing 42.
[0024] FIG. 8 schematically illustrates a sequential
steam-production method 100 in accordance to one or more
embodiments. With additional reference to FIGS. 1-7, sequential
steam-production completion 10 is deployed 110 in wellbore 24. As
will be understood by those skilled in the art with benefit of this
disclosure, completion 10 can be utilized for cyclical steam
stimulation (CSS) methods. Lower completion 20 is landed and set in
wellbore 12. Upper completion 22 is then deployed in the wellbore
and stinger 44 is landed in the polished bore receptacle 28 of
packer 26. An isolation device 32 in lower completion 20 may be
utilized to isolate formation 16 from the upper portion of the
wellbore as desired. Downhole steam generator (combustor) 36 is
fluidly coupled with a water supply, fuel supply and air
supply.
[0025] Fuel 56, air 60, and water 62 are supplied 120 to DSG 36.
Controller 40 may be utilized to control the supply of fuel, air
and water to DSG 36 and to operate DSG 36 to generate 130 steam 74.
Steam 74 is exhausted through discharge 48 past valve 50 and
through lower completion 20 and is injected into formation 16.
Barrier 52 may be operated or activated in production tubing 42 to
close the flow path during steaming operations. Barrier 52 is shown
activated in FIG. 1 with a plug 53 (dashed lines) deployed and
landed at barrier 52 (e.g. nipple). In accordance with some
embodiments barrier 52 may be a valve.
[0026] When steaming operations are completed DSG 36 may be
shut-down 140 and the air, water, and fuel supplies to DSG 36
closed. In accordance to some embodiments, the well or formation 16
may be suspended for a period of time, i.e. soak period, before
placing the well on production. During the soak period the
production tubing may be closed by barrier 52 (e.g. plug 53) and
valve 50 isolates DSG 36 from back flow of steam 74 and formation
fluid 72. In accordance to embodiments, upper completion 22 is not
pulled out of the wellbore while the well soaks.
[0027] The well is placed 150 on production for example by opening
barrier 52. In accordance with one or more embodiments, completion
22 is not pulled out of the wellbore between termination 140 of
steaming and or soaking operations and placing 150 the well on
production. In the FIG. 1 depiction, barrier 52 may be opened by
intervening for example through wellhead 24 and removing plug 53
for example via slick line, wireline, or coiled tubing. Once
barrier 52 is open, formation fluid 72 may be produced through
lower completion 20 into production tubing 42 and to surface
14.
[0028] In accordance to some embodiments, artificial lift (i.e.
secondary lift) may be desired to produce formation fluid 72 to the
surface. Artificial lift devices 68 incorporated in completion 22
may be operated 160 to aid in producing formation fluid 72 to the
surface. In accordance to some embodiments, artificial lift device
68 may be a operated via control line 38. In some embodiments,
artificial lift device 68 is a gas lift valve. Gas, for example
supply 56, is directed from fuel supply tubing 54 into production
tubing 42 through gas lift valve 68. In accordance to some
embodiments, artificial lift device 68 is a jet pump. Power fluid,
i.e. water 62, may be supplied for example from water tubing 66 or
other locations. For example, DSG 36 may be operated to produce a
hot effluent that may be directed from steam generator discharge 48
to artificial lift device 68. The hot effluent may be diverted from
discharge 48 between DSG 36 and valve 50 whereby the hot effluent
(e.g. steam 74) acts as gas lift mechanism for a thermal jet
pump.
[0029] The foregoing outlines features of several embodiments of
sequential steam injection to production completions and methods so
that those skilled in the art may better understand the aspects of
the disclosure. Those skilled in the art should appreciate that
they may readily use the disclosure as a basis for designing or
modifying other processes and structures for carrying out the same
purposes and/or achieving the same advantages of the embodiments
introduced herein. Those skilled in the art should also realize
that such equivalent constructions do not depart from the spirit
and scope of the disclosure, and that they may make various
changes, substitutions and alterations herein without departing
from the spirit and scope of the disclosure. The scope of the
invention should be determined only by the language of the claims
that follow. The term "comprising" within the claims is intended to
mean "including at least" such that the recited listing of elements
in a claim are an open group. The terms "a," "an" and other
singular terms are intended to include the plural forms thereof
unless specifically excluded.
* * * * *