Methods and systems for monitoring a subterranean formation and wellbore production
Methods of monitoring conditions within a wellbore comprise providing a plurality of signal transmitters and a plurality of signal receivers within the wellbore. Marker materials configured with a particular characteristic may interact with signals generated by the plurality of signal transmitters are introduced into the wellbore. The marker materials interact with the signals, forming modified signals. The modified signals are received by the plurality of signal receivers. The plurality of receivers are configured to measure at least one of acoustic activity and an electromagnetic field to determine a location of the marker materials. The electrical conductivity and the magnetism of produced fluids may also be measured to determine a producing zone of the produced fluid. Downhole systems including the marker materials and also disclosed.
1. A method of detecting a location of fluids within a wellbore, the method comprising:
providing a plurality of signal transmitters and a plurality of signal receivers in a wellbore in a subterranean formation;
injecting first marker particles having a first characteristic acoustic activity into a first zone of the subterranean formation and attaching the first marker particles to organic surfaces within the first zone, wherein attaching the first marker particles to organic surfaces comprises adhering molecules or functional groups of the first marker particles configured to adhere to at least one of asphaltenes, alkanes, clays, and biological incrustation within the first zone;
injecting second marker particles having a second characteristic acoustic activity different than the first characteristic acoustic activity into a second zone of the subterranean formation and attaching the second marker particles to organic surfaces within the second zone, wherein attaching the second marker particles to organic surfaces comprises adhering molecules or functional groups of the second marker particles configured to adhere to at least one of asphaltenes, alkanes, clays, and biological incrustation within the second zone;
generating an acoustic signal with at least one of the plurality of signal transmitters and transmitting the signal through the first marker particles and the second marker particles; and
detecting a reflected acoustic signal from the first marker particles and detecting a reflected acoustic signal from the second marker particles with at least one signal receiver of the plurality of signal receivers and detecting a location of at least one of the first marker particles and the second marker particles.
2. The method of claim 1 , further comprising stimulating the subterranean formation responsive to movement of at least one of the first marker particles and the second marker particles.
3. The method of claim 1 , further comprising detecting at least one of an acoustic activity and an electromagnetic field within the subterranean formation prior to injecting the first marker particles and injecting the second marker particles into the subterranean formation.
4. The method of claim 1 , wherein providing a plurality of signal transmitters and a plurality of signal receivers in a wellbore comprises providing a production string comprising a plurality of signal transmitters and a plurality of signal receivers attached to a fiber optic cable.
5. The method of claim 1 , wherein providing a plurality of signal transmitters and a plurality of signal receivers in a wellbore comprises providing a first plurality of signal transmitters and a first plurality of signal receivers within the first zone and providing a second plurality of signal transmitters and a second plurality of signal receivers within the second zone.
6. The method of claim 1 , wherein:
injecting first marker particles having a first characteristic acoustic activity into a first zone of the subterranean formation comprises injecting first marker particles having a first shape into the first zone; and
injecting second marker particles having a second characteristic acoustic activity different than the first characteristic acoustic activity into a second zone of the subterranean formation comprises injecting second marker particles having a second shape into the second zone.
7. The method of claim 1 , wherein:
injecting first marker particles having a first characteristic acoustic activity into a first zone of the subterranean formation comprises injecting first marker particles into fractures of the subterranean formation; and
injecting second marker particles having a second characteristic acoustic activity different than the first characteristic acoustic activity into a second zone of the subterranean formation comprises injecting second marker particles into a frac pack assembly.
8. The method of claim 1 , wherein:
injecting first marker particles having a first characteristic acoustic activity into a first zone of the subterranean formation comprises injecting first marker particles comprising nanoparticles into the first zone; and
injecting second marker particles having a second characteristic acoustic activity different than the first characteristic acoustic activity into a second zone of the subterranean formation comprises injecting second marker particles comprising proppants into the second zone.
9. The method of claim 1 , wherein detecting a reflected acoustic signal from the first marker particles and detecting a reflected acoustic signal from the second marker particles with at least one signal receiver of the plurality of signal receivers and detecting a location of at least one of the first marker particles and the second marker particles comprises logging the at least one of the detected reflected acoustic signal from the first marker particles and from the second marker particles.
10. The method of claim 1 , further comprising detecting at least one of an electrical conductance and a magnetism of at least one of the first marker particles and the second marker particles in a produced fluid to determine a source of the produced fluid.
11. A method of detecting a flow of hydrocarbons through fractures in a subterranean formation, the method comprising:
mixing, with a fracturing fluid, first marker particles surrounded by a first encapsulant configured to release the first marker particles at a first temperature, pressure, or salinity of a first zone of a subterranean formation;
fracturing the first zone of the subterranean formation with the fracturing fluid and adhering the first marker particles to the subterranean formation within the fractures of the first zone;
mixing, with another fracturing fluid, second marker particles surrounded by a second encapsulant configured to release the second marker particles at a second, different temperature, pressure, or salinity of a second zone of the subterranean formation;
fracturing the second zone of the subterranean formation with the another fracturing fluid and adhering the second marker particles to the subterranean formation within the fractures of the second zone; and
detecting at least one of an electrical conductivity of a produced fluid, a magnetism of the produced fluid, an acoustic activity within at least one of the first zone and second zone, and an electromagnetic field within at least one of the first zone and the second zone.
12. The method of claim 11 , wherein mixing, with a fracturing fluid, first marker particles comprises mixing first marker particles comprising hollow marker particles with the fracturing fluid.
13. The method of claim 11 , wherein mixing, with another fracturing fluid, second marker particles comprises mixing second marker particles comprising solid marker particles with the another fracturing fluid.
14. The method of claim 11 , wherein:
mixing, with a fracturing fluid, first marker particles comprises mixing first marker particles configured to be acoustically active with the fracturing fluid; and
mixing, with another fracturing fluid, second marker particles comprises mixing second marker particles configured to be at least one of electromagnetically active, exhibit a characteristic electrical conductivity, and exhibit a characteristic magnetism with the another fracturing fluid.
15. The method of claim 11 , wherein:
mixing, with a fracturing fluid, first marker particles comprises mixing electrically conductive marker particles with the fracturing fluid; and
mixing, with another fracturing fluid, second marker particles comprises mixing electrically resistive marker particles with the another fracturing fluid.
16. The method of claim 11 , wherein:
fracturing the first zone of the subterranean formation comprises fracturing the subterranean formation in a first horizontal zone of the subterranean formation; and
fracturing of the second zone of the subterranean formation comprises fracturing the subterranean formation in a second horizontal zone of the subterranean formation.
17. A downhole system, comprising:
a wellbore intersecting a plurality of zones within a subterranean formation;
a plurality of signal transmitters and a plurality of signal receivers extending along the wellbore adjacent the plurality of zones;
first marker particles within the subterranean formation, the first marker particles exhibiting a first characteristic acoustic activity and comprising molecules or functional groups configured to adhere to at least one of asphaltenes, alkanes, clays, and biological incrustation; and
second marker particles within the subterranean formation, the second marker particles exhibiting a second characteristic acoustic activity different than the first characteristic acoustic activity, and comprising molecules or functional groups configured to adhere to at least one of asphaltenes, alkanes, clays, and biological incrustation.
18. The method of claim 1 , further comprising injecting third marker particles having a third characteristic acoustic activity different than the first characteristic acoustic activity and the second characteristic acoustic activity into a third zone of the subterranean formation.
19. The method of claim 1 , further comprising selecting the first marker particles to comprise functional groups configured to adhere to at least one of asphaltenes, alkanes, clays, and biological incrustation.
20. The method of claim 1 , wherein:
injecting first marker particles having a first characteristic acoustic activity comprises injecting first marker particles comprising a coating exhibiting the first characteristic acoustic activity; and
injecting second marker particles having a second characteristic acoustic activity comprises injecting second marker particles comprising a coating exhibiting the second characteristic acoustic activity.