WO2014022121A1 - Telemetric chemical injection assembly - Google Patents
Telemetric chemical injection assembly Download PDFInfo
- Publication number
- WO2014022121A1 WO2014022121A1 PCT/US2013/051234 US2013051234W WO2014022121A1 WO 2014022121 A1 WO2014022121 A1 WO 2014022121A1 US 2013051234 W US2013051234 W US 2013051234W WO 2014022121 A1 WO2014022121 A1 WO 2014022121A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- valve
- injection
- fluid
- assembly
- line
- Prior art date
Links
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
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
- E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing, limiting or eliminating the deposition of paraffins or like substances
Definitions
- the well is often outfitted with chemical injection equipment to enhance ongoing recovery efforts without the requirement of intervention.
- most of the well may be defined by a smooth steel casing that is configured for the rapid uphole transfer of hydrocarbons and other fluids from a formation.
- a buildup of irregular occlusive scale, wax and other debris may occur at the inner surface of the casing or tubing and other architecture so as to restrict flow.
- Such debris may even form over perforations in the casing, screen, or slotted pipe thereby also hampering hydrocarbon flow into the main borehole of the well from the surrounding formation.
- each port delivers a predetermined rate of chemical mix when directed from surface equipment. That is to say, different ports at different locations are generally unable to activated while others are left closed. Rather, by way of a single delivery line, all ports are generally on or all are turned off.
- each port may be independently turned on or off at surface so as to allow for downhole ports to be independently activated.
- this type of system would require a dedicated delivery line for each and every port, thus, dramatically increasing completions equipment and installation expense.
- isolation techniques may be employed. That is, as in the case of stimulation and other zonally directed applications, different downhole zones may be isolated for sake of targeted delivery.
- packers or other isolating downhole features may be employed as a means of targeting chemical injection delivery from multiple ports. For example, one downhole region may be isolated in a manner that prevents chemical delivery thereto while allowing such delivery elsewhere.
- shutting down production for sake of attaining isolation results in applications that are no more cost-effective or time saving than the original types of interventions which chemical injection systems are configured to help avoid.
- a "smart" chemical injection assembly utilizing telemetry includes a mandrel housing coupled to a downhole tubular with an electric line that runs from an oilfield surface to the mandrel in a land well or offshore well.
- a fluid injection line is provided that also runs from the oilfield surface to the mandrel in a land well or offshore well.
- a power telemetry module is coupled to the electric line.
- an electric actuator that is coupled to the injection line may be provided for governing fluid injection.
- one or both of the module and the actuator may be secured within the mandrel housing.
- FIG. 1 is a side cross-sectional view of an embodiment of a telemetric chemical injection assembly disposed in a well.
- Fig. 2A is an enlarged view of an embodiment of an injection sub of the assembly of Fig. 1 and corresponding downhole fluid flow.
- Fig. 2B is an enlarged view of an alternate embodiment of an injection sub of the assembly with alternate corresponding downhole fluid flow.
- FIG. 3 is an overview of an oilfield employing an embodiment of the assembly of Fig. 1 for tailored regulation of injection fluids at multiple well zones.
- Fig. 4A is an alternate embodiment of the injection sub of Fig. 2B, equipped to accommodate a secondary injection line.
- Fig. 4B is another alternate embodiment of the injection sub, outfitted with multiple injection valves.
- FIG. 5 is a flow-chart summarizing an embodiment of employing a telementric chemical injection assembly within a well.
- Embodiments are described with reference to certain configurations of completions hardware that make use of chemical injection assemblies.
- completions are depicted and described which utilize a chemical injection assembly to help prevent scale and other buildup in a manner that may be telemetrically directed.
- different injection points in different well locations may be independently directed from an oilfield surface even though a common injection line may be utilized.
- a variety of different completion architectures may benefit from utilization of such an injection assembly.
- an injection sub or mandrel housing
- an actuator valve to govern injection and a power module.
- the valve may be directly and independently powered and controlled via telemetric and fluid injection lines running thereto from surface.
- a side cross-sectional view of an embodiment of a telemetric chemical injection assembly 100 is depicted within a well 180.
- the assembly 100 makes up a portion of completions hardware that is disposed below casing 185 and a production packer 1 10. Further, the assembly 100 is positioned across multiple production regions 190, 195. More specifically, a zonal isolation packer 120 is provided about a production tubular 107. Thus, separate annular spaces 105, 106 adjacent the tubular 107 may be zonally isolated from one another whereas a common fluid channel 103 is defined within the tubular 107.
- Zonal isolation at production regions 190, 195 as described above may allow for tailored recovery of production fluids.
- the tubular 107 may be outfitted with a separate flow control valve 115, 1 16, exposed to the isolated annular space 105, 106.
- a hydraulic or other suitable control line 1 17 may be utilized to independently open or close the valves 115, 1 16.
- production through a slotted liner 187, screen, perforated liner or similar hardware where utilized, at either formation region 190, 195 may be regulated via the open or closed valve 115, 116.
- each zonally isolated annular space 105, 106 is equipped with its own mandrel housing or injection sub 101, 102.
- a chemical injection fluid mix may be directed at each space 105, 106, the liner 187 or other downhole hardware so as to impede production inhibiting buildup.
- the mix may even be directed internally at the tubular channel 103 (see Fig. 2B).
- the valves 160, 162 may be an electrically powered actuator of plunger, gas lift, solenoid valve, electric motor or other metering variety.
- the valves may include fully opened, fully closed and variable choke positions.
- each valve 160, 162 may be supplied with its own dedicated fluid line which may be controlled from the oilfield surface 300, this may be extremely cost prohibitive (see Fig. 3). Therefore, the embodiment of Fig. 1 reveals the use of a single injection line 150 routed to each valve 160, 162 in combination with a telemetric line 155 so as to more fully and practically take advantage of such tailored delivery.
- the telemetric line 155 of Fig. 1 may be a conventional electric line or other suitable communication line for downhole use.
- the line 155 is routed through a power telemetry module 170, 171 in order to supply the power for independently opening or closing each valve 160, 162 as directed.
- These modules 170, 171 are shown disposed within the subs 101, 102. However, in other embodiments, alternative locations may be utilized. Further, such modules 170, 171 may be made available for sake of monitoring and communicating downhole conditions such as pressure and/or temperature. Thus, an added feature of such modules 170, 171 may now be to advantageously serve as a supportive platform for independent powerable control over each valve 160, 162 in a "smart" fashion.
- FIG. 2A an enlarged view of an embodiment of one of the injection subs 102 of the assembly of Fig. 1 is shown.
- fluid flow in the area is apparent. More specifically, production fluid 250 is shown moving uphole within the channel 103 of the production tubular 107 whereas injection fluid 200 is shown released from the valve 162 at the injection point 163. So, for example, the injection fluid 200 may serve to prevent occlusive buildup at the well formation interface of the slotted liner 187 and the depicted production region 195.
- an operator or control unit 310 may ensure that the flow control valve 1 16 is in an open or 'choked' position whenever the injection valve 162 is in an open position (see Fig. 3).
- a shiftable member 216 of the flow control valve 116 may be directed to open the valve 116 by a conventional control line 117.
- a conventional power/data cable may be utilized.
- opening of the injection valve 162 for sake of chemical injection delivery is two-fold. That is, the valve 162 may be supplied with the noted injection fluid 200 by way of the noted injection line 150. Further, tailored control over opening and/or the degree of opening of the valve 162 may be directed by another line (i.e. the telemetric line 155).
- the independent control over chemical injection delivery is directed through a telemetric line 155.
- This may be a conventional electronic or other suitable cable.
- the line 155 may be routed from surface to a power telemetry module 171 as detailed above. That is, the module 171 may serve a function of acquiring and relaying data relative to temperature, pressure and perhaps other location-based well characteristics (note the exposed outlet to the tubular channel 103). However, the module 171 may also advantageously serve the added function providing power and communicative relay to the injection valve 162 (note the electrical branch 255 of the line 155 routed to the valve 162). Thus, independent control over the valve 162 may be exercised from the oilfield surface 300.
- this same type of telemetric layout may be repeated at multiple downhole subs 101, 102 (see Fig. 1).
- independent "intelligent" control over each valve 160, 162 by way of a single main telemetric line 155 may be provided (see Fig. 3).
- FIG. 2B an enlarged view of an alternate embodiment of the injection sub 102 is depicted.
- the injection valve 162 and injection point 163 are reoriented so as to deliver injection fluid 200 within the channel 103 of the production tubing 107 as opposed to at the surrounding annular space 106.
- this may be advantageous where the sub 102 is located further uphole adjacent well casing 185. That is, the fluid 200 may be directed at impeding buildup at internal tubular components as opposed to the slotted liner 187 as shown in Fig. 2A.
- the same intelligent, independently controllable manner of injection may be directed from the oilfield surface 300 of Fig. 3.
- FIG. 3 an overview of an oilfield 300 is shown, whereat an embodiment of the assembly 100 of Fig. 1 is disposed within a well 180. More specifically, a more schematic view of the assembly 100 is shown allowing for tailored regulation of injection fluid 200 at different downhole production regions 190, 195. More specifically, production and chemical injection are both closed off relative the more downhole region 195. For example, where water is being produced or for any number of other reasons, a determination may be made to effectively shut off the region 195. Nevertheless, a determination to continue recovery of production fluids from points below the region 195 may also be made. Further, and perhaps more significantly in terms of the depicted figure, a determination may similarly be made to continue recovery and chemical injection at the other region 190.
- chemical injection fluid 200 is delivered in the vicinity of one region 190 so as to inhibit buildup at the slotted liner or screen or perforated liner 187 as described above.
- This same fluid 200 is recovered within the tubular 107 along with production fluids 250 for transport uphole.
- the ability of the assembly 100 to efficiently recover these fluids 200, 250 at one region 190 while keeping injection and recovery closed off from another region 195 is rendered practical and effective by the availability of cooperative valves 160, 162 and modules 170, 171 as detailed hereinabove (see Fig. 1).
- an electrically actuated plunger type valve 160, 162 in conjunction with a readily available power telemetry module 170, 171 may be particularly beneficial in allowing for the construction of such an assembly 100.
- an operator may intelligently direct chemical injection as detailed above through the use of surface equipment. More specifically, a control unit 310 may be provided for sake of directing operations, including the exercise of control over the telemetric line 155 and downhole valves as detailed above. Further, a chemical mix tank 320 may be provided for supplying of injection fluid 200 to the injection line 150. Thus, later recovery of injection 200 and production 250 fluids may ultimately be routed through the well head 330 and a production line 340 for processing.
- a secondary line 400 is routed to the location of the injection valve 162.
- a fluid other than the chemical injection fluid 200 may also be delivered through the valve 162. That is, while fluid of any practical type may be directed through the injection line 150, there may be circumstances in which different fluid types are segregated from one another. For example, an acid injection type of stimulation fluid may be delivered through the secondary line 400 at certain targeted points in time whereas the noted injection fluid 200 is delivered through the injection line 150 on a more regular or continuous basis.
- FIG. 4B another alternate embodiment of the injection sub 102 is depicted.
- the sub 102 is outfitted with multiple injection valves 162, 462, 463 all drawing actuation from the same power telemetry module 171.
- FIG. 4B the availability of multiple valves 162, 462, 463 allows for targeting of different delivery locations. That is, embodiments such as that depicted in Fig. 1 reveal different subs 101, 102 at different depths being independently serviceable via a single injection line 150. However, in Fig. 4B another embodiment is shown that reveals the possibility of also servicing different locations at roughly the same depth of the same sub 102. More specifically, the primary injection valve 162 is shown servicing the channel 103 at the interior of the production tubular 107 similar to the configuration of Fig. 2B. Further, the secondary valves 462, 463 are shown simultaneously servicing the annular space 106 similar to the configuration of Fig. 2A. [0034] Referring now to Fig.
- a flow-chart is shown summarizing an embodiment of employing a telemetric chemical injection assembly within a well.
- a chemical injection fluid may be selectively delivered through a line to any one of many injection points downhole (see 530). Subsequently, over the same line, the fluid may be delivered to another of the points as indicated at 550. Once more, as noted at 570, these same injection points may be serviced by a secondary line for delivery of another fluid such as an acid-based stimulation fluid.
- the fluids may be recovered with production up to an oilfield surface as indicated at 590.
- Embodiments described hereinabove include a telemetric or "smart" chemical injection assembly which is able to provide targeted chemical injection at multiple downhole depths or locations in a tailored manner. That is, without the requirement of a multitude of individually dedicated chemical injection lines, multiple delivery locations may be independently regulated for delivery from an oilfield surface. Further, no intervening isolations are required in order to achieve such targeted or tailored delivery. Indeed, one downhole location may be opened and serviced while another remains turned off and vice versa. This may be achieved in a cost-effective manner through the use of available power telemetry modules.
Abstract
Description
Claims
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
BR112015002179A BR112015002179A2 (en) | 2012-08-01 | 2013-07-19 | telemetry chemical injection assembly for positioning in a well in an oilfield, and method of delivering chemical injection fluid to a well in an oilfield |
NO20150145A NO20150145A1 (en) | 2012-08-01 | 2015-02-03 | Telemetric chemical injection assembly |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/564,236 US20120292044A1 (en) | 2011-02-03 | 2012-08-01 | Telemetric chemical injection assembly |
US13/564,236 | 2012-08-01 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2014022121A1 true WO2014022121A1 (en) | 2014-02-06 |
Family
ID=50028433
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2013/051234 WO2014022121A1 (en) | 2012-08-01 | 2013-07-19 | Telemetric chemical injection assembly |
Country Status (3)
Country | Link |
---|---|
BR (1) | BR112015002179A2 (en) |
NO (1) | NO20150145A1 (en) |
WO (1) | WO2014022121A1 (en) |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US11542798B2 (en) | 2021-02-08 | 2023-01-03 | Baker Hughes Oilfield Operations Llc | Variable orifice valve for gas lift mandrel |
US11692405B2 (en) | 2021-02-10 | 2023-07-04 | Baker Hughes Oilfield Operations Llc | Guide sleeve for use with side pocket mandrel |
US11725490B2 (en) | 2020-11-11 | 2023-08-15 | Baker Hughes Oilfield Onerations LLC | Gas lift side pocket mandrel with modular interchangeable pockets |
US11933150B2 (en) | 2021-01-14 | 2024-03-19 | Baker Hughes Oilfield | Electric remote operated gas lift mandrel |
Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5544705A (en) * | 1995-01-13 | 1996-08-13 | Atlantic Richfield Company | Method for injecting fluid into a wellbore |
US20030150619A1 (en) * | 2002-02-11 | 2003-08-14 | Meaders Michael Wade | Hydraulic control assembly for actuating a hydraulically controllable downhole device and method for use of same |
US7419937B2 (en) * | 2002-12-19 | 2008-09-02 | Schlumberger Technology Corporation | Method for providing treatment chemicals in a subterranean well |
US7886825B2 (en) * | 2006-09-18 | 2011-02-15 | Schlumberger Technology Corporation | Formation fluid sampling tools and methods utilizing chemical heating |
US20110079398A1 (en) * | 2009-10-06 | 2011-04-07 | Schlumberger Technology Corporation | Multi-point chemical injection system for intelligent completion |
-
2013
- 2013-07-19 WO PCT/US2013/051234 patent/WO2014022121A1/en active Application Filing
- 2013-07-19 BR BR112015002179A patent/BR112015002179A2/en not_active IP Right Cessation
-
2015
- 2015-02-03 NO NO20150145A patent/NO20150145A1/en not_active Application Discontinuation
Patent Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5544705A (en) * | 1995-01-13 | 1996-08-13 | Atlantic Richfield Company | Method for injecting fluid into a wellbore |
US20030150619A1 (en) * | 2002-02-11 | 2003-08-14 | Meaders Michael Wade | Hydraulic control assembly for actuating a hydraulically controllable downhole device and method for use of same |
US7419937B2 (en) * | 2002-12-19 | 2008-09-02 | Schlumberger Technology Corporation | Method for providing treatment chemicals in a subterranean well |
US7886825B2 (en) * | 2006-09-18 | 2011-02-15 | Schlumberger Technology Corporation | Formation fluid sampling tools and methods utilizing chemical heating |
US20110079398A1 (en) * | 2009-10-06 | 2011-04-07 | Schlumberger Technology Corporation | Multi-point chemical injection system for intelligent completion |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US11725490B2 (en) | 2020-11-11 | 2023-08-15 | Baker Hughes Oilfield Onerations LLC | Gas lift side pocket mandrel with modular interchangeable pockets |
US11933150B2 (en) | 2021-01-14 | 2024-03-19 | Baker Hughes Oilfield | Electric remote operated gas lift mandrel |
US11542798B2 (en) | 2021-02-08 | 2023-01-03 | Baker Hughes Oilfield Operations Llc | Variable orifice valve for gas lift mandrel |
US11692405B2 (en) | 2021-02-10 | 2023-07-04 | Baker Hughes Oilfield Operations Llc | Guide sleeve for use with side pocket mandrel |
Also Published As
Publication number | Publication date |
---|---|
NO20150145A1 (en) | 2015-02-03 |
BR112015002179A2 (en) | 2017-08-01 |
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