CN103403292A - A method for producing hydrocarbons and installation for application thereof - Google Patents
A method for producing hydrocarbons and installation for application thereof Download PDFInfo
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- CN103403292A CN103403292A CN2012800099961A CN201280009996A CN103403292A CN 103403292 A CN103403292 A CN 103403292A CN 2012800099961 A CN2012800099961 A CN 2012800099961A CN 201280009996 A CN201280009996 A CN 201280009996A CN 103403292 A CN103403292 A CN 103403292A
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- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 51
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 49
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 24
- 238000009434 installation Methods 0.000 title abstract 2
- 239000012530 fluid Substances 0.000 claims abstract description 65
- 238000000034 method Methods 0.000 claims abstract description 34
- 230000000694 effects Effects 0.000 claims abstract description 13
- 230000009974 thixotropic effect Effects 0.000 claims abstract description 10
- 239000004215 Carbon black (E152) Substances 0.000 claims description 43
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 17
- 238000002347 injection Methods 0.000 claims description 13
- 239000007924 injection Substances 0.000 claims description 13
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 10
- 239000004020 conductor Substances 0.000 claims description 8
- 239000000945 filler Substances 0.000 claims description 8
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims description 7
- 239000011231 conductive filler Substances 0.000 claims description 7
- 239000000741 silica gel Substances 0.000 claims description 6
- 229910002027 silica gel Inorganic materials 0.000 claims description 6
- 229910052799 carbon Inorganic materials 0.000 claims description 4
- LLYXJBROWQDVMI-UHFFFAOYSA-N 2-chloro-4-nitrotoluene Chemical compound CC1=CC=C([N+]([O-])=O)C=C1Cl LLYXJBROWQDVMI-UHFFFAOYSA-N 0.000 claims description 3
- 239000000571 coke Substances 0.000 claims description 3
- 230000001934 delay Effects 0.000 claims description 3
- 239000000428 dust Substances 0.000 claims description 3
- 238000005538 encapsulation Methods 0.000 claims description 3
- 150000002148 esters Chemical class 0.000 claims description 3
- 229910044991 metal oxide Inorganic materials 0.000 claims description 3
- 150000004706 metal oxides Chemical class 0.000 claims description 3
- 238000006073 displacement reaction Methods 0.000 claims description 2
- -1 hydrocarbon hydrocarbon Chemical class 0.000 claims 1
- 230000003111 delayed effect Effects 0.000 abstract description 2
- 230000003247 decreasing effect Effects 0.000 abstract 1
- 210000004027 cell Anatomy 0.000 description 9
- 241000772415 Neovison vison Species 0.000 description 7
- 230000008901 benefit Effects 0.000 description 4
- 239000007789 gas Substances 0.000 description 4
- 239000000463 material Substances 0.000 description 4
- 238000005086 pumping Methods 0.000 description 4
- 239000004576 sand Substances 0.000 description 4
- 238000010793 Steam injection (oil industry) Methods 0.000 description 3
- 238000010796 Steam-assisted gravity drainage Methods 0.000 description 3
- 239000000499 gel Substances 0.000 description 3
- 238000010438 heat treatment Methods 0.000 description 3
- 239000010426 asphalt Substances 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 239000000567 combustion gas Substances 0.000 description 2
- 238000007599 discharging Methods 0.000 description 2
- 239000000446 fuel Substances 0.000 description 2
- 230000002045 lasting effect Effects 0.000 description 2
- 239000002184 metal Substances 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- 239000012266 salt solution Substances 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 240000007594 Oryza sativa Species 0.000 description 1
- 235000007164 Oryza sativa Nutrition 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 239000002775 capsule Substances 0.000 description 1
- 235000013339 cereals Nutrition 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 238000002485 combustion reaction Methods 0.000 description 1
- 125000004122 cyclic group Chemical group 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 239000000412 dendrimer Substances 0.000 description 1
- 210000001787 dendrite Anatomy 0.000 description 1
- 229920000736 dendritic polymer Polymers 0.000 description 1
- 238000007598 dipping method Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000005611 electricity Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 210000003722 extracellular fluid Anatomy 0.000 description 1
- 238000004401 flow injection analysis Methods 0.000 description 1
- 238000005243 fluidization Methods 0.000 description 1
- 239000003349 gelling agent Substances 0.000 description 1
- 239000005431 greenhouse gas Substances 0.000 description 1
- 230000001788 irregular Effects 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 239000000843 powder Substances 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 235000009566 rice Nutrition 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000013049 sediment Substances 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 238000010408 sweeping Methods 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/2401—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection by means of electricity
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/2405—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection in association with fracturing or crevice forming processes
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
The invention relates to a method for producing hydrocarbons in a porous reservoir of hydrocarbons, comprising making at least two wells (13, 14) in the reservoir of hydrocarbons, creating an electrically conducting path (16) in the reservoir between the wells with a thixotropic fluid or fluid with a delayed gelling effect, establishing an electric connection between the wells through the conducting path, wherein the passing of the current dissipates heat by the Joule effect and the heat warms up the reservoir by thermic conductivity, and decreasing the viscosity of the hydrocarbons. The invention also relates to an installation for applying the method.
Description
The present invention relates to the method for the production of hydrocarbon, and relate to be used to the device of using the method.
The present invention is positioned at the scope of producing viscous oil and mink cell focus, in order to produce described viscous oil and mink cell focus, needs fluidisation (or reducing viscosity).Application relates to the mink cell focus that is included in sand asphalt.
The decline of oil viscosity is by providing heat obtainable.The means that realize this have a lot.What know most is steam injection, no matter and the technology of using (CCS (vapor recycle advocate approach how, Cyclic Steam Simulation), vapour drives method or SAGD (SAGD method, Steam Assisted Gravity Drainage).Can also mention the injection (also referred to as situ combustion) of air.
Document WO-A-2005010320 has described to generate in compacted formation (that is, imporosity or permeability) via fracturing by injecting the conductive supporting agent and has kept open vertical fracture planes.Then drilling level well, it intersects with described fracture planes, guarantees thus electric continuity.This is to realize on can be by the compacting plate of pressure break, and each Production Regional needs three mouthfuls of water horizontal wells.
Yet this solution can not be applied to the mink cell focus deposit, because they can not be by pressure break.This solution is being also complicated aspect the layout of its well.
Need to be for the production of the method that is easier to use of hydrocarbon.
For this reason, the present invention proposes a kind of method of producing hydrocarbon for the porous reservoir at hydrocarbon, described method comprises:
-at least two mouthfuls of wells of manufacturing in hydrocarbon reservoir,
-with thixotropic fluid or have in the reservoir of fluid between described well of delay gelating effect and produce conductive path,
-sets up electrical connection by described conductive path between described well, the passing through via the Joule effect loses heat of electric current, described heat is conducted reservoir is warmed by heat, the viscosity of reduction hydrocarbon.
According to a replacement scheme, described method comprises described fluid is injected into one of described well, exerts pressure in the second well, and described pressure is lower than the pressure in medium, to produce the enough barometric gradients that are used for making fluid displacement.
According to a replacement scheme, described method comprises described fluid is injected into one of described well, and conductive filler is present in fluid or is introduced in fluid by circulation after injecting fluid when injecting fluid.
According to a replacement scheme, described fluid comprises the conductive filler that is selected from coke blacking, graphite powder, CNT or metal oxide.
According to a replacement scheme, described method comprises described fluid is injected into one of described well, and the filler that causes the fluid thixotroping or have a delay gelating effect is present in fluid or is introduced in fluid by circulation after injecting fluid when injecting fluid.
According to a replacement scheme, the generation of path comprises water is injected into one of described well, then injects the silica gel that is loaded with carbon dust, and described silica gel has be used to the encapsulation ester that delays to solidify.
According to a replacement scheme, the location of the conductive path of the well that injects along fluid is undertaken by checking deferred well logging (deferred logging).
According to a replacement scheme, the conduction between described well is that the metal-back via the well that contacts with described conductive path carries out.
According to a replacement scheme, the conduction between described well is to be undertaken by the electrode at described bottom place, and described electrode is present in the bottom of described well and forms in the curing thixotropic fluid of conductive path.
According to a replacement scheme, the conduction between described well is to be undertaken by the electrode at described bottom place, described electrode the bottom that is present in described well and with conductive material that conductive path is electrically connected in.
According to a replacement scheme, produce hydrocarbon, the gas of a part is for generation of described conductive path being supplied with the electric power of electric current.
According to a replacement scheme, fluid is that water and electric current are direct current or alternating current.
The invention still further relates to the device be used to the production hydrocarbon of using preceding method.
According to a replacement scheme, described device comprises vertical, level or the well that turns to or the combination in these orientation.
According to a replacement scheme, well be part vertical or turn to, the well that the fluid Injection Well is set to polygonal production hydrocarbon surrounds.
By reading to the detailed description of following embodiment of the present invention that only provide as an example and in conjunction with the accompanying drawing shown in following, it is obvious that further feature of the present invention and advantage will become:
-Fig. 1 to 3, the example of the embodiment of well;
-Fig. 4 to 6, for the production of the example of the configuration of the device of hydrocarbon;
-Fig. 7, an example of device.
The present invention relates to a kind of method for the production of hydrocarbon, it is included in hydrocarbon reservoir makes at least two mouthfuls of wells.Then described method comprises with thixotropic fluid or has in the reservoir of fluid between well of delayed gel effect and produce conductive path, and set up electrical connection via conductive path between well, passing through via the Joule effect loses heat of electric current, described heat is conducted reservoir is warmed by heat, reduces thus the viscosity of hydrocarbon.The generation of lasting conductive path realizes in reservoir in simpler mode, and this is conducive to the production that reservoir warms and simplified hydrocarbon.
Fig. 1 to 3 shows the example for the production of the device of the hydrocarbon of heavy and viscous oil or pitch form.Target oil is contained in porous media.Fig. 1 to 3 shows the reservoir 11 that is comprised of more or less dipping bed.The mink cell focus of described hydrocarbon 12 for can not simply being extracted by pumping, these oil viscosities make them be difficult to be produced.
, according to first step, make well 13 and 14 penetrate ground in order to arrive the reservoir that contains hydrocarbon 12.According to Fig. 1 to 3, for example, described well is shown as vertical.The direction of well is unimportant, and the present invention not only can implement with simple peupendicular hole, and in some configuration can with turn to or horizontal well even, perhaps the combination in these orientation is implemented.The be separated by distance of approximately tens of rice (5 to 50m) of described well.
, in order to make path 16,, according to second step, will have the fluid of suppressing and be injected in the first well 13 that is called as Injection Well.Described pressure higher than the pressure in reservoir in order to allow fluid to penetrate in reservoir.If described pressure does not have far away in porous media, seepage flow will to occur higher than the pressure in reservoir.The passage that develops will be dendrimer (dendrite) form.If described pressure is far away higher than the pressure of reservoir, by expansion will generate wider passage (such as the fluid of water not only can be by described medium initial hole but also can clean out by " removing " grains of sand its road), can carry larger electric power.This will not have any fracture, because this is plasticity, non-brittle medium.In the second well 14, apply the pressure lower than the pressure in described medium, to produce enough barometric gradients between so-called Injection Well and a rear well.
Described fluid can be water especially.Utilize the bad mobility ratio between the oil of injected water and appropriate position.In fact, due to the strong viscosity of mink cell focus, the mobility of water is higher than the mobility of oil.This causes the fluid finger-type channel (fluidic fingering) between well 13 and 14 in reservoir., if described medium is heterogeneous, will form path in the most permeable layer of sand so.This is a kind of phenomenon that prevents of usually attempting, for example by injection of polymer in injected water.Injected water need to not processed before injection, even can use salt solution.
According to Fig. 1 to 3, as a shown well of example, be wherein vertical, path 16 along the location of described well the vertical direction of the well of Fig. 1 to 3 (in this case, according to) complete by checking deferred well logging.Seek correlation between the well that is used for location and target injection.In the situation that the several relevant permeable layer between well, with one that selects in the most suitable institute implementation method.
According to third step, the finger-type channel of fluid allows to produce path 16 between well 13 and 14.In order to make the lasting also conduction of this path 16, use thixotropic fluid, described thixotropic fluid (while stopping injecting) when being cut into zero solidifies, perhaps by adding in advance filler such as the gelling agent with delayed-action.Also can make injection fluid (such as water) perfect with the filler that causes injecting the fluid conduction.
The filler that causes injecting fluid (such as water) conduction can be for for example: coke blacking, graphite powder, CNT, metal powder or metal oxide.Their amount must be sufficient: account for 30 to 80 volume % of conductive material, preferred 60 to 70 volume %.
Can be converted on the meaning of solid-state particularity from liquid state from having, described fluid is thixotropic or has the delay gelating effect.Standing, described fluid incites somebody to action structuring again until it has the aspect (viscosity is infinitely great) of solid.This guarantees the durability of conductive path 16.This allows to produce passage, " the natural cable " of conduction in reservoir.
Make the filler of described fluid (for example water) thixotroping can be gel.The final response of conductive cable is that good temperature tolerance (because this is a heater) and good mechanical strength are to resist the barometric gradient that produces in reservoir by the pumping hydrocarbon.
In an alternative arrangements, after injecting fluid, in the beginning of second step, just directly comprise conductive filler.In the second alternative arrangements, have the fluid of delayed-action in injection after, in the beginning of second step, just comprise the filler that causes the fluid thixotroping.This delayed-action can be for example by being encapsulated in filler in the capsule that is covered with film and obtaining.These two kinds of configurations can be made up.
According to an example of the embodiment of conductive path 16, injected water, to produce path, then injects the silica gel that is loaded with carbon dust, and described silica gel has be used to the encapsulation ester that delays to solidify.
, according to the 4th step, in order to ensure conduction between well 13 and 14, electric current is injected wherein.Injection is interrupted, and makes the conductive path 16 that obtains thus and solidify be connected to generator (GE) 18.By Joule effect, electric current allows to provide heat energy and heating hydrocarbon to reduce its viscosity.This makes hydrocarbon more easily flow, and this allows their easier quilts to produce., according to Fig. 1 to 3, can realize with several means the electrical connection at well 13 and 14 places.
In the first embodiment that is electrically connected to, well can connect as shown in Figure 1, by carefully guarantee in shell 20 and reservoir conductive path 16 for example with the contacting of special touch 22, directly carry out described electrical connection via the metal-back 20 of described well 13 and 14.Guarantee generator 18, well 13,14 shell 22 and the electrical connection between path 16.
In the second embodiment that is electrically connected to, described well can connect as shown in Figure 2, and when described material was present in the bottom of well 13 and 14, described electrical connection was by being arranged to make electrode 24 be arranged in through the curing conductive material, carrying out of path 16.In other words, thixotropic fluid is solidified not only for generation of path 16, also be present in the bottom of well 13 and 14.This bottom in the well 13 that electrically contacts with path 16 and 14 produces bank (reserve) 26, from the supply of electric power of generator 18, is transferred to bank 26.Guarantee electrode 24, well 13 and the bank 26 at place, 14 bottoms and the electrical connection between path 16 at generator 18, bottom place.
In the 3rd embodiment that is electrically connected to, well can connect as shown in Figure 3, the material that forms path 16 is not present in well 13,14 bottom (for example because subsequently for example by " fraising " or boring well, well is cleaned), guarantees the continuity of the electricity between generator 18 and path 16 by being incorporated into electrode 24 in the conductive material 28 in well 13,14 bottoms.Material 28 can be carbon or the gravel metal pulverulent material (or " ruckle ").
Certainly, described embodiment provides as an example, and also nonrestrictive.
The electric current that uses can have a few types.This can be for direct current or low-frequency current so that by the Joule effect Heat of Formation, it can be for high frequency electric in order to produce the heating of interstitial fluid (particularly Interstitial Water) by Lenz's law.Described electric current is for exchanging or DC current.
The first well 13 preferably is not used in the pumping hydrocarbon, because it is blocked by conductive path 16.On the other hand, hydrocarbon can be pumped to the second well 14 or other is aboveground.
In the configuration of an optimization, several Injection Wells (as the first well 13) and producing well (as the second well 14) can be associated according to the different configuration that provides in Fig. 4 to 6 for example.In these configurations, well is vertical.In these configurations, the first well 13 by 14, other the second well around, well 14 is arranged according to the geometry of for example regular polygon or irregular polygon.
Fig. 4 shows the configuration of well layout, comprises by its (for example under high pressure) and injects the well 13 of conductor flow and comprise around well 13 basically with square a plurality of wells 14 of arranging.In these wells 14, well 141,142,143,144 can be for being used for (low pressure) outlet well of conductive filler such as gel.Well 141,142,143,144 can be positioned on the summit of square configuration.Path 16 can be along the diagonal of described square configuration between well 13 and well 141,142,143,144.Well 141,142,143,144 may optionally be hydrocarbon production well.In well 14, well 145,146,147,148 can be only hydrocarbon production well.These wells 145,146,147,148 can for example be positioned on the limit of square configuration.The production of hydrocarbon is completed by pumping in the well producing hydrocarbon, and the viscosity of hydrocarbon is by providing heat energy to be minimized by adding heat passage 16.
Fig. 5 shows the well layout configurations, comprises by its (for example under high pressure) and injects the well 13 of conductor flow and comprise a plurality of wells 14 of around well 13, basically with hexagon-shaped configuration, arranging.Well 14 is depicted as the outlet well for conductive filler.Well 14 may optionally be hydrocarbon production well.Other hydrocarbon production well can for example provide as the limit along hexagonal structure in Fig. 4.Production such as Fig. 4 of hydrocarbon carry out.
Fig. 6 shows for the sedimental scheme of recovery of hydrocarbons, wherein repeats the configuration of Fig. 5.Conductor flow Injection Well 13 is shared outlet well 14 and/or hydrocarbon production well with adjacent well 13.The production of hydrocarbons place can also comprise the configuration of Fig. 4 or the repetition of any other configuration.
The method according to this invention is based on the character of rock and fluid, this character is shortcoming for the situation of heavy and viscous oil reservoir usually, in fact, seek to benefit from preferential process according to the present invention, it is shortcoming as the method that makes water or steam injection that this process keeps the method for pressure or dredging (sweeping) for needs by injection high fluidity fluid.
Well to be drilled is simple well, and it is rarely used in such application.Using of the method is simple.
The invention has the advantages that there is no CO according to the present invention
2Direct discharging.The present invention can be applied to the deposit that utilized in advance by steam injection; , by the present invention, do not need to produce steam or rely on burning.Required electric power can not discharge CO
2Prerequisite under and produce.The fluid that uses can be undressed salt solution, and this is because we can not run into the problem of the solid sediment that may encounter in steam generator.
The present invention allows to reduce land area and avoids emission greenhouse gas.The electric power that uses can produce such as for example fuel cell or combustion gas turbine by any mode of present existence.
Fig. 7 shows device 10 and comprises the example that the electric power of reservoir 11 use of mink cell focus or sand asphalt is supplied with for generation of exploitation.The figure shows an example of device 10, wherein conductive path 16 has been set up.Described electric power is supplied with via well 13 and is arrived path 16.Well 14 is producing well.Hydrocarbon heats and their reduced viscosity in the zone 32 of by conductive path 16, being crossed, this allows them by well 14, to be pumped out.Arrow 34 shows flowing of the hydrocarbon through heating that is present in reservoir 11.Be contained in hydrocarbon in reservoir by oil and gas composition.Well 14 is produced hydrocarbon.Eliminator 40 will come the hydrocarbon of artesian well to be separated into respectively by arrow 36 and 42 gas and the oil of discharging via arrow 38.Gas partly is used to produce electric power and be sent to processing unit 44.The system for generation of electric power 46 is supplied with in this unit.For generation of the system of electric power be for example fuel cell, combustion gas turbine, maybe can be with any other generator of gas-operated.Electric power produces and allows via well 13 supply passageways 16.Therefore, advantage is to produce electric power by present device original position.
Claims (15)
1. a method that is used for producing at the porous reservoir of hydrocarbon hydrocarbon, comprise
-manufacturing at least two mouthfuls of wells (13,14) in the described reservoir of hydrocarbon,
-with thixotropic fluid or have in the reservoir of fluid between described well of delay gelating effect and produce conductive path (16),
-set up electrical connection by described conductive path between described well, the passing through via the Joule effect loses heat of electric current, described heat is conducted described reservoir is warmed by heat, reduces thus the viscosity of hydrocarbon.
2. method according to claim 1, comprise described fluid be injected in one of described well, exerts pressure in the second well, and described pressure is lower than the pressure in medium, to produce the enough barometric gradients that are used for making described fluid displacement.
3. method according to claim 1 and 2, comprise described fluid be injected in one of described well, and conductive filler is present in described fluid or is incorporated into described fluid by circulation after injecting described fluid when injecting described fluid.
4. the described method of any one according to claim 1 to 3, wherein said fluid comprises the conductive filler that is selected from coke blacking, graphite powder, CNT or metal oxide.
5. the described method of any one according to claim 1 to 4, comprise described fluid is injected in one of described well, the filler that causes described fluid thixotroping or have a delay gelating effect is present in described fluid or is introduced in described fluid by circulation after injecting described fluid when injecting described fluid.
6. the described method of any one according to claim 1 to 5, the generation of wherein said path comprise water are injected in one of described well, then inject the silica gel that is loaded with carbon dust, and described silica gel has be used to the encapsulation ester that delays to solidify.
7. the described method of any one according to claim 1 to 6, wherein the location of the described well (13) that is injected into along fluid of conductive path (16) is undertaken by checking deferred well logging.
8. the described method of any one according to claim 1 to 7, the conduction between wherein said well are that the metal-back (20) via the described well that contacts with described conductive path (16) carries out.
9. the described method of any one according to claim 1 to 7, conduction between wherein said well is to be undertaken by the electrode at described bottom place (24), and described electrode (24) is in the bottom that is present in described well and in forming the curing thixotropic fluid of described conductive path (16).
10. the described method of any one according to claim 1 to 7, conduction between wherein said well is to be undertaken by the electrode at described bottom place (24), described electrode (24) the bottom that is present in described well and with conductive material (28) that described conductive path (16) is electrically connected in.
11. according to claim 1 to 10, the described method of any one, wherein produce hydrocarbon, the part of gas is for generation of described conductive path (16) being supplied with the electric power of electric current.
12. the described method of any one according to claim 1 to 11, wherein said fluid are water and described electric current is direct current or alternating current.
13. production of hydrocarbons device (10) that is used for using the described method of according to claim 1 to 12 any one.
14. device according to claim 13, comprise vertical, level or the well (13,14) that turns to or the combination in these orientation.
15. the described device of any one according to claim 13 or 14, wherein said well is for part is vertical or turn to, and the well of the production hydrocarbon that the fluid Injection Well is arranged with polygon surrounds.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| FR1151464A FR2971809B1 (en) | 2011-02-23 | 2011-02-23 | PROCESS FOR PRODUCING HYDROCARBONS AND INSTALLATION FOR IMPLEMENTING THE SAME |
| FR1151464 | 2011-02-23 | ||
| PCT/EP2012/053052 WO2012113854A1 (en) | 2011-02-23 | 2012-02-23 | A method for producing hydrocarbons and installation for application thereof |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN103403292A true CN103403292A (en) | 2013-11-20 |
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| CN2012800099961A Pending CN103403292A (en) | 2011-02-23 | 2012-02-23 | A method for producing hydrocarbons and installation for application thereof |
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| CN (1) | CN103403292A (en) |
| AP (1) | AP3712A (en) |
| CA (1) | CA2826339C (en) |
| FR (1) | FR2971809B1 (en) |
| RU (1) | RU2013138298A (en) |
| WO (1) | WO2012113854A1 (en) |
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| CN105605658A (en) * | 2016-01-13 | 2016-05-25 | 肖玉化 | Method for installing heating module on foundation surface |
| WO2018029501A1 (en) | 2016-08-12 | 2018-02-15 | Total Sa | Method of preparation of a hydrocarbon production installation, related production process and installation |
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| WO2003018709A1 (en) * | 2001-08-27 | 2003-03-06 | Halliburton Energy Services, Inc. | Electrically conductive oil-based mud |
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| EP1634938A1 (en) * | 2004-09-02 | 2006-03-15 | Schlumberger Technology B.V. | Viscoelastic fluids for oilfield uses |
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| CN101641495A (en) * | 2007-03-22 | 2010-02-03 | 埃克森美孚上游研究公司 | Granular electrical connections for in situ formation heating |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| FR2920782B1 (en) * | 2007-09-07 | 2010-07-30 | Arkema France | DRILLING FLUID CONTAINING CARBON NANOTUBES |
-
2011
- 2011-02-23 FR FR1151464A patent/FR2971809B1/en not_active Expired - Fee Related
-
2012
- 2012-02-23 AP AP2013007120A patent/AP3712A/en active
- 2012-02-23 CA CA2826339A patent/CA2826339C/en not_active Expired - Fee Related
- 2012-02-23 CN CN2012800099961A patent/CN103403292A/en active Pending
- 2012-02-23 WO PCT/EP2012/053052 patent/WO2012113854A1/en active Application Filing
- 2012-02-23 RU RU2013138298/03A patent/RU2013138298A/en unknown
Patent Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP1296019A1 (en) * | 1998-11-17 | 2003-03-26 | Golder Sierra LLC | Azimuth control of hydraulic vertical fractures in unconsolidated and weakly cemented soils and sediments |
| CN1430696A (en) * | 2000-04-24 | 2003-07-16 | 国际壳牌研究有限公司 | Heating system and method |
| WO2003018709A1 (en) * | 2001-08-27 | 2003-03-06 | Halliburton Energy Services, Inc. | Electrically conductive oil-based mud |
| CN1806090A (en) * | 2003-06-24 | 2006-07-19 | 埃克森美孚上游研究公司 | Methods of treating a subterranean formation to convert organic matter into producible hydrocarbons |
| EP1634938A1 (en) * | 2004-09-02 | 2006-03-15 | Schlumberger Technology B.V. | Viscoelastic fluids for oilfield uses |
| CN101641495A (en) * | 2007-03-22 | 2010-02-03 | 埃克森美孚上游研究公司 | Granular electrical connections for in situ formation heating |
| WO2010129174A1 (en) * | 2009-05-05 | 2010-11-11 | Exxonmobil Upstream Research Company | Converting organic matter from a subterranean formation into producible hydrocarbons by controlling production operations based on availability of one or more production resources |
Also Published As
| Publication number | Publication date |
|---|---|
| FR2971809B1 (en) | 2014-02-28 |
| CA2826339A1 (en) | 2012-08-30 |
| RU2013138298A (en) | 2015-03-27 |
| FR2971809A1 (en) | 2012-08-24 |
| AP2013007120A0 (en) | 2013-09-30 |
| CA2826339C (en) | 2018-07-10 |
| WO2012113854A1 (en) | 2012-08-30 |
| AP3712A (en) | 2016-05-31 |
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