US20150041129A1 - Steam injection and production completion system - Google Patents
Steam injection and production completion system Download PDFInfo
- Publication number
- US20150041129A1 US20150041129A1 US14/451,159 US201414451159A US2015041129A1 US 20150041129 A1 US20150041129 A1 US 20150041129A1 US 201414451159 A US201414451159 A US 201414451159A US 2015041129 A1 US2015041129 A1 US 2015041129A1
- Authority
- US
- United States
- Prior art keywords
- dsg
- completion
- tubing
- lift device
- production tubing
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/243—Combustion in situ
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.
Description
- 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.
- 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.
- 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.
- 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.
- 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.
- 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.
-
FIG. 1 illustrates a well system in which embodiments of sequential steam injection and production completions and method can be utilized. -
FIG. 2 illustrates a steam injection and production completion having three tubing strings in accordance with one or more embodiments. -
FIG. 3 illustrates a steam injection and production completion having four tubing strings in accordance with one or more embodiments. -
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. -
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. -
FIG. 8 is a diagram of sequential steam injection to production method in accordance to one or more embodiments. - 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.
- 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.
-
FIG. 1 is an illustration of awell system 5 in which sequential steam injection to production methods and completions, generally denoted by thenumeral 10, may be incorporated and utilized. Awellbore 12 extends from asurface 14 to aformation 16 which is in communication withwellbore 12. At least a portion ofwellbore 12 may be lined withcasing 18.Completion 10 includes alower completion 20 installed downhole and aboveformation 16 and anupper completion 22 deployed belowwellhead 24 and landed inlower completion 20. -
Lower completion 20 may include a packer 26 (i.e. production packer) having a polished bore receptacle (PBR) 28 and atail pipe 30 extending belowpacker 26. Lower completion may include anisolation device 32 such as a valve, flow control device, or nipple cooperative with aclosure member 34. Closuremember 34 is illustrated inFIG. 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 someembodiments isolation device 32 may be for example a nipple andclosure member 34 may be a plug. For example the plugs may be coiled tubing, wireline, or slickline deployed. - 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 intoformation 16.Upper completion 22 may include acontrol 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. InFIG. 1 ,control line 38 is illustrated connecting asurface controller 40 withdownhole steam generator 36. With additional reference toFIGS. 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). -
Upper completion 22 in accordance to one or more embodiments includes aproduction 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 orleg 45 that is continuous with a single outlet flow path orleg 49 and a second inlet flow path orleg 47 that is combined into singleoutlet flow path 49.Production tubing 42 is connected tofirst leg 45 of inverted Y-tool 46 and is connected to stinger 44 throughsingle leg 49. -
Steam discharge 48 of DSG 36 is connected to stinger 44 through inverted Y-tool 46.Steam discharge 48 is connected tosecond leg 47 of inverted Y-tool 46 and connected to stinger 44 throughsingle leg 49. Inverted Y-tool 46 is illustrated located adjacent tostinger 44 for the purpose of illustrating and describing other features of the sequential steam-production completion. - 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 intoDSG 36 from belowlower completion 20, e.g. formation fluid, or fromproduction tubing 42.Production tubing 42 may include abarrier 52, for example a valve or retrievable plug, to selectivelyclose production tubing 42 for example to prevent steam from being produced to the surface. -
Upper completion 22 includes two tubing strings extending from surface to provide fuel and air toDSG 36. For example,fuel supply tubing 54 is deployed fromwellhead 24 toDSG 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 fromwellhead 24 toDSG 36.Air tubing 58 is connected to an air source orsupply 60 which may include a compressor. With reference toFIGS. 1 , 2 and 4,water 62 may be supplied from awater supply 64 into wellbore 12 (i.e. annulus) and intoinlet 65 ofDSG 36.Water supply 64 may include pumps. In accordance to some embodiments, for example as illustrated in FIGS. 3 and 5-7, awater supply tubing 66 may connectDSG 36 to the surface andwater supply 64. - In accordance to one or more embodiments,
upper completion 22 may include anartificial lift device 68 for example as illustrated inFIGS. 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 toFIGS. 4 and 4 ,artificial lift devices 68 are illustrated as pumps, such as electric submersible pumps and positive displacement pumps. -
FIG. 6 illustrates gas lift type (e.g. valve) ofartificial lift device 68 coupled for example to fuelsupply tubing 54 through acontrol valve 70. Gas (e.g. natural gas) from supply 56 (FIG. 1 ) may be directed fromfuel supply tubing 54 intogas lift device 68 to reduce the gravity of theformation fluid 72 inproduction tubing 42 to aid production to the surface.FIG. 7 illustrates sequential steam-production completion utilizing a jet pump type ofartificial lift device 68. For example, a power fluid (e.g. water) fromwater supply tubing 66 can be directed for example viacontroller 40 andcontrol valve 70 tojet pump 68.Controller 40 may manipulate the application of power fluid to operate thejet pump 68 stroke up and down inproduction tubing 42. In accordance to some embodiments, DSG 36 (e.g. combustor) can be operated to produce a hot effluent that is directed fromdischarge 48 toartificial 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 thedischarge 48 without need of an artificial lift device downhole. The hot effluent flows downward from theDSG 36 through the Y-tool and into theproduction tubing 42. -
FIG. 8 schematically illustrates a sequential steam-production method 100 in accordance to one or more embodiments. With additional reference toFIGS. 1-7 , sequential steam-production completion 10 is deployed 110 inwellbore 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 inwellbore 12.Upper completion 22 is then deployed in the wellbore andstinger 44 is landed in thepolished bore receptacle 28 ofpacker 26. Anisolation device 32 inlower completion 20 may be utilized to isolateformation 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. -
Fuel 56,air 60, andwater 62 are supplied 120 toDSG 36.Controller 40 may be utilized to control the supply of fuel, air and water toDSG 36 and to operateDSG 36 to generate 130steam 74.Steam 74 is exhausted throughdischarge 48past valve 50 and throughlower completion 20 and is injected intoformation 16.Barrier 52 may be operated or activated inproduction tubing 42 to close the flow path during steaming operations.Barrier 52 is shown activated inFIG. 1 with a plug 53 (dashed lines) deployed and landed at barrier 52 (e.g. nipple). In accordance with someembodiments barrier 52 may be a valve. - When steaming operations are completed
DSG 36 may be shut-down 140 and the air, water, and fuel supplies toDSG 36 closed. In accordance to some embodiments, the well orformation 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) andvalve 50 isolates DSG 36 from back flow ofsteam 74 andformation fluid 72. In accordance to embodiments,upper completion 22 is not pulled out of the wellbore while the well soaks. - 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 betweentermination 140 of steaming and or soaking operations and placing 150 the well on production. In theFIG. 1 depiction,barrier 52 may be opened by intervening for example throughwellhead 24 and removingplug 53 for example via slick line, wireline, or coiled tubing. Oncebarrier 52 is open,formation fluid 72 may be produced throughlower completion 20 intoproduction tubing 42 and to surface 14. - 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 incompletion 22 may be operated 160 to aid in producingformation fluid 72 to the surface. In accordance to some embodiments,artificial lift device 68 may be a operated viacontrol line 38. In some embodiments,artificial lift device 68 is a gas lift valve. Gas, forexample supply 56, is directed fromfuel supply tubing 54 intoproduction tubing 42 throughgas 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 fromwater tubing 66 or other locations. For example,DSG 36 may be operated to produce a hot effluent that may be directed fromsteam generator discharge 48 toartificial lift device 68. The hot effluent may be diverted fromdischarge 48 betweenDSG 36 andvalve 50 whereby the hot effluent (e.g. steam 74) acts as gas lift mechanism for a thermal jet pump. - 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.
Claims (20)
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.
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US14/451,159 US20150041129A1 (en) | 2013-08-08 | 2014-08-04 | Steam injection and production completion system |
CA 2858664 CA2858664A1 (en) | 2013-08-08 | 2014-08-07 | Steam injection and production completion system |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US201361863574P | 2013-08-08 | 2013-08-08 | |
US14/451,159 US20150041129A1 (en) | 2013-08-08 | 2014-08-04 | Steam injection and production completion system |
Publications (1)
Publication Number | Publication Date |
---|---|
US20150041129A1 true US20150041129A1 (en) | 2015-02-12 |
Family
ID=52447602
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US14/451,159 Abandoned US20150041129A1 (en) | 2013-08-08 | 2014-08-04 | Steam injection and production completion system |
Country Status (2)
Country | Link |
---|---|
US (1) | US20150041129A1 (en) |
CA (1) | CA2858664A1 (en) |
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20190178065A1 (en) * | 2017-12-12 | 2019-06-13 | Baker Hughes, A Ge Company, Llc | Method for real time flow control adjustment of a flow control device located downhole of an electric submersible pump |
US11441403B2 (en) | 2017-12-12 | 2022-09-13 | Baker Hughes, A Ge Company, Llc | Method of improving production in steam assisted gravity drainage operations |
US20230143015A1 (en) * | 2020-07-02 | 2023-05-11 | Schlumberger Technology Corporation | Completion isolation system with tubing movement compensator |
Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20050103497A1 (en) * | 2003-11-17 | 2005-05-19 | Michel Gondouin | Downhole flow control apparatus, super-insulated tubulars and surface tools for producing heavy oil by steam injection methods from multi-lateral wells located in cold environments |
US20110036576A1 (en) * | 2007-07-06 | 2011-02-17 | Schultz Roger L | Heated fluid injection using multilateral wells |
-
2014
- 2014-08-04 US US14/451,159 patent/US20150041129A1/en not_active Abandoned
- 2014-08-07 CA CA 2858664 patent/CA2858664A1/en not_active Abandoned
Patent Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20050103497A1 (en) * | 2003-11-17 | 2005-05-19 | Michel Gondouin | Downhole flow control apparatus, super-insulated tubulars and surface tools for producing heavy oil by steam injection methods from multi-lateral wells located in cold environments |
US20110036576A1 (en) * | 2007-07-06 | 2011-02-17 | Schultz Roger L | Heated fluid injection using multilateral wells |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20190178065A1 (en) * | 2017-12-12 | 2019-06-13 | Baker Hughes, A Ge Company, Llc | Method for real time flow control adjustment of a flow control device located downhole of an electric submersible pump |
US10794162B2 (en) * | 2017-12-12 | 2020-10-06 | Baker Hughes, A Ge Company, Llc | Method for real time flow control adjustment of a flow control device located downhole of an electric submersible pump |
US11441403B2 (en) | 2017-12-12 | 2022-09-13 | Baker Hughes, A Ge Company, Llc | Method of improving production in steam assisted gravity drainage operations |
US20230143015A1 (en) * | 2020-07-02 | 2023-05-11 | Schlumberger Technology Corporation | Completion isolation system with tubing movement compensator |
Also Published As
Publication number | Publication date |
---|---|
CA2858664A1 (en) | 2015-02-08 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US9945203B2 (en) | Single trip completion system and method | |
US8079417B2 (en) | Wireline retrievable dsg/downhole pump system for cyclic steam and continuous steam flooding operations in petroleum reservoirs | |
CA2691769C (en) | Method and apparatus for multilateral multistage stimulation of a well | |
NZ607028A (en) | Apparatus and method for downhole steam generation and enhanced oil recovery | |
US8985215B2 (en) | Single trip multi-zone completion systems and methods | |
US8851189B2 (en) | Single trip multi-zone completion systems and methods | |
NO337872B1 (en) | Method and apparatus for continuous injection of fluid into a wellbore while maintaining safe valve operation | |
US20150041126A1 (en) | Bypass steam injection and production completion system | |
US11111764B2 (en) | Wellbore annular safety valve and method | |
US20090090499A1 (en) | Well system and method for controlling the production of fluids | |
RU2296213C2 (en) | Packer pumping plant for well formations operation | |
US20150041129A1 (en) | Steam injection and production completion system | |
RU2438043C2 (en) | Garipov pump unit for simultaneous separate operation of wells (versions) | |
US20150136406A1 (en) | Subsea Intervention Plug Pulling Device | |
RU95741U1 (en) | HARIPOV PUMP INSTALLATION FOR SIMULTANEOUS-SEPARATE OPERATION OF WELLS (OPTIONS) | |
CN103470233A (en) | Heavy oil reservoir natural gas huff-and-puff oil production process system and oil production method | |
US10480307B2 (en) | Method for providing well safety control in a remedial electronic submersible pump (ESP) application | |
US10570714B2 (en) | System and method for enhanced oil recovery | |
EP2840228A2 (en) | Wellbore Annular Safety Valve and Method | |
RU2743119C1 (en) | Adjustable gas lift unit | |
RU2012135910A (en) | INSTALLATION FOR PRODUCTION OF NEFI WITH SIMULTANEOUS-SEPARATE DISPOSAL OF GARIPOV'S PLASTIC WATER AND METHOD FOR ITS IMPLEMENTATION (OPTIONS) | |
RU154945U1 (en) | Borehole wellhead fittings | |
Bybee | Monobore Completion System Provides Low-Cost Completion Option | |
Carpenter | Successful Application of Intelligent Completions in Al Khalij Field | |
Ehtesham et al. | Remote-Activation Safety Valves and Coiled Tubing, Jointed-Tubing Hybrid String: A Novel Well-Intervention Technology |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: SCHLUMBERGER TECHNOLOGY CORPORATION, TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:MANI, SAIKUMAR;BOYLE, BRUCE;VERZWYVELT, DAVID;AND OTHERS;SIGNING DATES FROM 20140814 TO 20140822;REEL/FRAME:033735/0701 |
|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |