CN113482586B - Marine thermal recovery viscous crude collection and transportation treatment process package - Google Patents
Marine thermal recovery viscous crude collection and transportation treatment process package Download PDFInfo
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- CN113482586B CN113482586B CN202110942445.1A CN202110942445A CN113482586B CN 113482586 B CN113482586 B CN 113482586B CN 202110942445 A CN202110942445 A CN 202110942445A CN 113482586 B CN113482586 B CN 113482586B
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- 238000000034 method Methods 0.000 title claims abstract description 28
- 230000008569 process Effects 0.000 title claims abstract description 26
- 238000011084 recovery Methods 0.000 title claims abstract description 17
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 117
- 238000004519 manufacturing process Methods 0.000 claims abstract description 67
- 238000004581 coalescence Methods 0.000 claims abstract description 62
- 239000010779 crude oil Substances 0.000 claims abstract description 57
- 239000003921 oil Substances 0.000 claims abstract description 48
- 239000004576 sand Substances 0.000 claims abstract description 33
- 239000012530 fluid Substances 0.000 claims description 47
- 238000002347 injection Methods 0.000 claims description 34
- 239000007924 injection Substances 0.000 claims description 34
- 239000012071 phase Substances 0.000 claims description 22
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 20
- 239000007791 liquid phase Substances 0.000 claims description 20
- 239000007788 liquid Substances 0.000 claims description 18
- 239000007789 gas Substances 0.000 claims description 13
- 238000011045 prefiltration Methods 0.000 claims description 11
- 229910052757 nitrogen Inorganic materials 0.000 claims description 10
- 241000191291 Abies alba Species 0.000 claims description 6
- 238000012423 maintenance Methods 0.000 claims description 6
- 238000000926 separation method Methods 0.000 claims description 6
- 230000001502 supplementing effect Effects 0.000 claims description 4
- 238000005406 washing Methods 0.000 claims description 4
- 235000020681 well water Nutrition 0.000 claims description 4
- 239000002349 well water Substances 0.000 claims description 4
- 239000002518 antifoaming agent Substances 0.000 claims description 3
- 239000003795 chemical substances by application Substances 0.000 claims description 3
- 230000005684 electric field Effects 0.000 claims description 3
- 239000003755 preservative agent Substances 0.000 claims description 3
- 230000002335 preservative effect Effects 0.000 claims description 3
- 230000001105 regulatory effect Effects 0.000 claims description 3
- 239000007790 solid phase Substances 0.000 claims description 3
- 230000009471 action Effects 0.000 claims description 2
- 238000005191 phase separation Methods 0.000 claims description 2
- 238000005507 spraying Methods 0.000 claims description 2
- 238000011161 development Methods 0.000 abstract description 6
- 238000000605 extraction Methods 0.000 description 5
- 230000008859 change Effects 0.000 description 3
- 239000000295 fuel oil Substances 0.000 description 3
- 238000010586 diagram Methods 0.000 description 2
- 238000010795 Steam Flooding Methods 0.000 description 1
- 230000003139 buffering effect Effects 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 230000001276 controlling effect Effects 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 230000018044 dehydration Effects 0.000 description 1
- 238000006297 dehydration reaction Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000005685 electric field effect Effects 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 238000010992 reflux Methods 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 239000013589 supplement Substances 0.000 description 1
Classifications
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- 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
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- 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
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/35—Arrangements for separating materials produced by the well specially adapted for separating solids
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- Mining & Mineral Resources (AREA)
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- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Fats And Perfumes (AREA)
Abstract
The invention discloses a marine thermal recovery thick oil gathering and transportation treatment process package. The offshore thermal recovery thick oil gathering and transportation treatment process package has the following structure: the metering manifold, the open-flow manifold and the production manifold are all connected with a thermal wellhead production tree, and a cold flow outlet of the qualified crude oil/water-containing crude oil heat exchanger is sequentially connected with a first production heater, an electrostatic coalescence primary separator, a second production heater and an electrostatic coalescence secondary separator; the oil phase outlet of the electrostatic coalescence secondary separator is sequentially connected with the pre-electric dewatering pump filter and the electric dewatering booster pump, the outlet of the electric dewatering booster pump is connected with the inlet of the electric dewatering device, the oil phase outlet is connected with the hot flow inlet of the qualified crude oil/water-containing crude oil heat exchanger, and the qualified crude oil produced by the hot flow outlet of the qualified crude oil/water-containing crude oil heat exchanger is transported out of the pump or is stored after being cooled; the water phase outlets of the electrostatic coalescence primary separator, the electrostatic coalescence secondary separator and the electric dehydrator are connected with a post-dewatering treatment system of the cyclone sand remover. The invention can be widely applied to the technical field of offshore thickened oil thermal recovery development engineering.
Description
Technical Field
The invention relates to a marine thermal recovery thick oil gathering and transportation treatment process package, and belongs to the technical field of marine thermal recovery thick oil development engineering.
Background
The thick oil has high viscosity and high density, and is usually produced from the stratum by adopting development modes such as steam huff and puff, steam flooding and the like, namely, injecting high-temperature and high-pressure steam into the stratum, reducing the viscosity of the crude oil of the stratum through heating. After the thick oil is extracted from the stratum, three main problems exist in the process treatment, on one hand, the dehydration of the thick oil is very difficult due to the high viscosity and small oil-water density difference of the thick oil; on the other hand, the thick oil thermal recovery is generally divided into a series of processes of heat injection, well stewing, open flow and the like, and the change of the gas and liquid amount of the produced fluid is large, the temperature change is large, and particularly the change is particularly severe in the open flow period; in addition, the heavy oil has high sand content, equipment and sea pipes are easy to damage, and the sand removal effect is poor when the cyclone sand remover is directly adopted for the heavy oil due to high viscosity of the heavy oil. The offshore platform has very limited area, and is difficult to adopt large-tank settlement, buffering and other processes on land, so that a targeted process needs to be developed to solve the problems in order to enable the thick oil heat collection and treatment process to be smoothly implemented on the sea.
Disclosure of Invention
The invention aims to provide a marine thick oil thermal recovery gathering and transportation treatment process package which is applied to the technical field of marine thick oil thermal recovery development engineering.
The invention provides a marine thick oil thermal recovery gathering and transportation treatment process package, which comprises a metering manifold, an open-flow manifold, a production manifold, an open-flow tank, a qualified crude oil/water-containing crude oil heat exchanger, an electrostatic coalescence primary separator, an electrostatic coalescence secondary separator and an electric dehydrator;
The metering manifold, the open flow manifold and the production manifold are all connected with a thermal production wellhead production tree, wherein the metering manifold is connected with a metering separator through a metering heater, the open flow manifold is connected with an anti-spraying tank, and a liquid phase outlet of the metering separator, a liquid phase outlet of the open flow tank and the production manifold are all connected with a cold flow inlet of the qualified crude oil/water-containing crude oil heat exchanger;
The cold flow outlet of the qualified crude oil/water-containing crude oil heat exchanger is sequentially connected with a first production heater, the electrostatic coalescence primary separator, a second production heater and the electrostatic coalescence secondary separator; the oil phase outlet of the electrostatic coalescence secondary separator is sequentially connected with the pre-electric dewatering pump filter and the electric dewatering booster pump, the outlet of the electric dewatering booster pump is connected with the inlet of the electric dewatering device, the water phase outlet of the electric dewatering device is connected with the inlet of the cyclone sand remover, the oil phase outlet is connected with the heat flow inlet of the qualified crude oil/water-containing crude oil heat exchanger, and qualified crude oil produced by the heat flow outlet of the qualified crude oil/water-containing crude oil heat exchanger is transported outwards through the pump or stored after being cooled;
And the water phase outlets of the electrostatic coalescence primary separator, the electrostatic coalescence secondary separator and the electric dehydrator are connected with a post-dewatering treatment system of the cyclone sand remover.
Specifically, the water phase outlets of the electrostatic coalescence primary separator and the electric dehydrator are directly connected with the inlet of the cyclone sand remover;
the water phase outlet of the electrostatic coalescence secondary separator is sequentially connected with a secondary back doping pump pre-filter and a secondary back doping pump and then connected with the inlet of the cyclone sand remover, and the inlet pressure of the cyclone sand remover is required to be more than or equal to 200kPaG.
Specifically, a liquid phase outlet of the cyclone sand remover is connected with an inlet of a production water buffer tank, and a solid phase outlet of the cyclone sand remover is connected with an inlet of a sand treatment system;
The outlet of the production water buffer tank is divided into three branches, one branch is connected with a production water back mixing pump through a production water back mixing pump inlet filter, and the outlet of the production water back mixing pump is connected with the inlet of the first production heater; the other branch is connected with an inlet of the power fluid booster pump through a power fluid booster pump inlet filter, an outlet of the power fluid booster pump is connected with an inlet of the power fluid injection pump, an outlet of the power fluid injection pump is connected with an inlet of a power fluid injection manifold, and an outlet of the power fluid injection manifold is connected with a thermal wellhead christmas tree; the third branch is connected with an inlet of the water treatment system.
Specifically, the open-flow tank, the electrostatic coalescence primary separator and the gas phase outlet of the electrostatic coalescence secondary separator are respectively connected with a cold emptying pipeline and a nitrogen maintenance pressure pipeline through pressure control valves, and the pressure in the tank is controlled by the two pressure control valves together, so that the pressure in the tank is ensured to be stable.
Specifically, the gas phase outlet pipeline of the metering separator is converged with the liquid phase outlet pipeline and then goes to the qualified oil/water-containing crude oil heat exchanger, the gas phase outlet is connected with the nitrogen pressure maintaining pipeline, and pressure control valves are arranged at the joints of the gas phase outlet and the nitrogen pressure maintaining pipeline and the liquid phase outlet and jointly control the pressure in the metering separator tank.
Specifically, the liquid level in the electrostatic coalescence primary separator is controlled by a control valve of a water outlet pipeline, and the oil-water interface level is controlled by a control valve of the outlet of the second production heater;
The liquid level in the electrostatic coalescence secondary separator is controlled by a secondary back-doped pump outlet control valve, and the oil-water interface is controlled by adjusting the rotating speed of an electric stripping booster pump through a frequency converter.
Specifically, the liquid level of the production water buffer tank is jointly controlled by a water source well water supplementing pipeline control valve and a production water back-mixing pump outlet control valve, and the outlet flow of the power liquid injection pump is regulated by the back-flowing production water buffer tank.
Specifically, the electrostatic coalescence primary separator and the electrostatic coalescence secondary separator are used for oil-gas-water three-phase separation, wherein an insulating electrode is arranged in a liquid phase area, oil-water separation is promoted by an electric field effect, the water content of an oil outlet of the electrostatic coalescence primary separator is about 50% -60%, and the electrostatic coalescence secondary separation pressure is lower, and is generally about 20 kPaG-200 kPaG;
The internal electrode of the electric dehydrator is a bare electrode, so that the inlet water content is not more than 30%, the outlet crude oil water content is less than 2% and the standard of qualified crude oil of heavy thickened oil is achieved;
The pressure in the electric dehydrator is controlled by a control valve of a cold flow outlet of the qualified crude oil/water-containing crude oil heat exchanger, and the oil-water interface is controlled by a water phase outlet control valve of the electric dehydrator;
And sand washing pipelines are arranged at the bottoms of the electrostatic coalescence primary separator, the electrostatic coalescence secondary separator and the electric dehydrator.
Specifically, the open-flow tank and the metering separator are vertical tank bodies, and a tipping bucket metering device is arranged in the open-flow tank and the metering separator for metering the flow of liquid phase;
the metering separator is connected with the metering manifold through a bypass pipeline, and when the temperature of the fluid is higher, the fluid directly enters the metering separator without being heated by the metering heater;
and the liquid phase outlets of the open-flow tank and the metering separator are provided with control valve positions for controlling the liquid level in the tank.
Specifically, the outlet of the thermal wellhead Christmas tree is connected with a preservative injection pipeline;
And the outlets of the metering manifold, the open-flow manifold and the production manifold are connected with an antiscaling agent injection pipeline, a demulsifier injection pipeline and a defoaming agent injection pipeline.
In the system of the invention, the secondary back-mixing pump is generally a centrifugal pump, the electric-stripping booster pump is generally a screw pump, the front of the pump is provided with a filter for protection, and the pump and the filter are required to be provided for standby.
The production water back-mixing pump and the power liquid booster pump generally adopt centrifugal pumps, filters are arranged in front of the pumps, the power liquid injection pump adopts plunger pumps, and the pumps and the filters are required to be arranged for standby.
When the system is used for carrying out the collection and transportation treatment of the offshore thermal recovery thickened oil, the inlet water content of the electrostatic coalescence primary separator reaches 80% or more through back mixing of produced water and water supplement of a water source well, and the water mixing point of the water source well is positioned at the inlet of a produced water buffer tank.
The oil content in the outlet water of the production water buffer tank is less than 3000-4000 ppm;
and the sand particle size of the power fluid at the outlet of the power injection manifold is less than or equal to 40 meshes.
The invention can be adjusted according to the oil property and oil extraction mode, when the oil viscosity is low and the density is small, the electrostatic coalescence insulated electrode in the electrostatic coalescence primary separator can be removed, and no electric field is applied any more; when the electric submersible pump is adopted for oil well oil extraction, instead of the jet pump, a pre-filter of a power fluid booster pump, the power fluid booster pump, a power fluid injection pump and a power fluid injection manifold are removed.
By adopting the technical scheme, the invention has the following advantages:
1. The invention adopts the electrostatic coalescence separator as the first-stage separator and the second-stage separator of well flow, improves the oil-water separation efficiency through the action of an electric field, and ensures the high-efficiency separation of thick oil and water.
2. The invention is provided with the independent open-flow manifold, the metering manifold, the open-flow tank and the metering separator, and the dump bucket metering device is arranged in the open-flow tank and the metering separator, so that the metering requirements of various development periods of thick oil thermal recovery can be met.
3. The invention solves the problem of sand removal of the marine thickened oil by mixing water and washing sand and separating and removing sand in production water.
4. The invention sets the process flow of power fluid circulation injection, and can realize the circulation utilization of the power fluid when the jet pump is adopted for oil extraction.
5. The water content of the crude oil produced by the method can meet the requirement of qualified crude oil, and the full-process treatment of the offshore thick oil is realized.
6. The invention shortens the residence time of oil-gas-water separation by utilizing high-efficiency treatment equipment, reduces the size of the tank body, and is suitable for offshore application.
Therefore, the invention can be widely applied to the technical field of offshore thick oil thermal recovery development engineering.
Drawings
FIG. 1 is a schematic diagram of the offshore thermal recovery thickened oil collection and transportation treatment process package of the invention.
Detailed Description
The experimental methods used in the following examples are conventional methods unless otherwise specified.
Materials, reagents and the like used in the examples described below are commercially available unless otherwise specified.
The invention is described below by taking a process package of a thick oil field in Bohai sea as an example, wherein the oil treatment capacity of the process package is 1909m 3/d, and a jet pump is adopted for oil extraction.
As shown in fig. 1, a schematic diagram of a thick oil collection and transportation treatment process package provided by the invention includes: metering manifold 1, open-flow manifold 2, production manifold 3, open-flow tank 4, metering heater 5, metering separator 6, acceptable crude oil/aqueous crude oil heat exchanger 7, first production heater 8, electrostatic coalescing primary separator 9, second production heater 10, electrostatic coalescing secondary separator 11, electric dehydrator 12, electric pre-pump filter 13, electric de-pressurizing pump 14, secondary pre-back-doping pump filter 15, secondary back-doping pump 16, cyclone sand remover 17, produced water buffer tank 18, produced water back-doping pump pre-filter 19, produced water back-doping pump 20, power fluid booster pump pre-filter 21, power fluid booster pump 22, power fluid injection pump 23, power fluid injection manifold 24.
The metering manifold 1, the discharge manifold 2 and the production manifold 3 are connected with a thermal wellhead christmas tree, the outlet of the metering manifold 1 is connected with the inlet of the metering heater 5, the outlet of the metering heater 5 is connected with the inlet of the metering separator 6, the discharge manifold 2 is connected with the inlet of the discharge tank 4, the liquid outlets of the discharge tank 4 and the metering separator 6 and the production manifold 3 are connected with the cold flow inlet of the qualified crude oil/water-containing crude oil heat exchanger 7, the cold flow outlet of the qualified crude oil/water-containing crude oil heat exchanger 7 is connected with the cold flow inlet of the first production heater 8, the cold flow outlet of the first production heater 8 is connected with the inlet of the electrostatic coalescence primary separator 9, the oil outlet of the electrostatic coalescence primary separator 9 is connected with the cold flow inlet of the second production heater 10, the cold flow outlet of the second production heater 10 is connected with the inlet of the electrostatic coalescence secondary separator 11, the oil outlet of the electrostatic coalescence secondary separator 11 is connected with the inlet of the crude oil before-removing pump 13, the outlet of the filter before-removing pump is connected with the inlet of the electric-increasing pump 14, the outlet of the electric-removing pump 14 is connected with the inlet of the electric-removing-increasing pump 12, the oil outlet of the qualified crude oil/water-containing crude oil is connected with the inlet of the electric-containing heat exchanger 12, the oil outlet of the electric-containing crude oil is connected with the qualified crude oil/water-containing heat exchanger 7 or the hot flow after the heat exchange fluid is discharged to the qualified fluid is cooled out of the heat exchanger or the hot flow of the hot fluid is discharged outside the heat exchanger through the heat exchanger 7.
Further, the open flow tank in the embodiment can bear 1 to 4 wells for open flow at the same time, the operating temperature is between 64 and 121 ℃, and the operating pressure is 750kPaG; a tipping bucket metering device is arranged in the metering separator, the operating temperature is 70-89.8 ℃, and the operating pressure is 750kPaG.
Further, the gas outlets of the open-flow tank 4, the electrostatic coalescence primary separator 9 and the electrostatic coalescence secondary separator 11 are connected with a maintenance pressure nitrogen pipeline and a cold emptying pipeline, and the tank pressures of the open-flow tank 4, the electrostatic coalescence primary separator 9 and the electrostatic coalescence secondary separator 11 are controlled by two pressure control valves at the joint of the gas outlets and the nitrogen maintenance pressure pipeline and the cold emptying pipeline.
Further, the gas outlet of the metering separator 6 is connected with a pressure maintaining nitrogen pipeline and a liquid outlet, and the pressure in the tank of the metering separator 6 is controlled by two pressure control valves at the connection part of the gas outlet, the nitrogen pressure maintaining pipeline and the liquid outlet pipeline.
Further, in the present example, the operation temperature of the electrostatic coalescing primary separator 9 was 80 ℃, the operation pressure was 550kPaG, the liquid phase residence time was 40 minutes, and the liquid phase outlet water content was 50%; the operating temperature of the electrostatic coalescence secondary separator 11 was 110 ℃, the operating pressure 140kPaG, the liquid phase residence time 40 minutes, and the outlet water content 30%; the operation temperature of the electric dehydrator is 110 ℃, the operation pressure is 550kPaG, the liquid phase residence time is 60 minutes, the mass water content of the exported crude oil is less than or equal to 2 percent, and the related water content requirement of qualified heavy thickened oil is met.
Further, the water outlet of the electrostatic coalescence primary separator 9 is connected with the inlet of the cyclone sand remover 17, the water outlet of the electrostatic coalescence secondary separator 11 is connected with the inlet of the secondary back doping pump pre-filter 15, the outlet of the secondary back doping pump pre-filter 15 is connected with the inlet of the secondary back doping pump 16, the outlet of the secondary back doping pump 16 is connected with the inlet of the cyclone sand remover 17, and the water outlet of the electric dehydrator 12 is connected with the inlet of the cyclone sand remover 17. The liquid phase outlet of the cyclone sand remover 17 is connected with the inlet of the production water buffer tank 18, the outlet of the production water buffer tank 18 is divided into three paths, and one path is connected with the inlet of the water treatment system; one path is connected with the inlet of a production water back mixing pump pre-filter 19, the outlet of the production water back mixing pump pre-filter 19 is connected with the inlet of a production water back mixing pump 20, and the outlet of the production water back mixing pump 20 is connected with the inlet of a production heater 8; the last way is connected with a filter 21 before a power fluid booster pump, an outlet of the filter 21 before the power fluid booster pump is connected with an inlet of a power fluid booster pump 22, an outlet of the power fluid booster pump 22 is connected with an inlet of a power fluid injection pump 23, an outlet of the power fluid injection pump 23 is connected with an inlet of a power fluid injection manifold 24, and an outlet of the power fluid injection manifold 24 is connected with a thermal wellhead christmas tree. The solid phase outlet of the cyclone sand remover 17 is connected with the inlet of the sand treatment system.
Further, in the embodiment, the power fluid injection pump 23 adopts 4-to-1 power fluid, and the single flow rate is 40 square/hour; the production water back-mixing pump 2 is 1, the single discharge capacity is 85 square/hour, and the water content of the crude oil entering the electrostatic coalescence primary separator 9 after mixing water can reach 80% or more.
Further, the water outlet control valve of the electrostatic coalescence primary separator 9 controls the liquid level in the tank, and the outlet control valve of the secondary heater 10 controls the oil-water boundary level in the tank. The outlet control valve of the secondary back doping pump 16 controls the liquid level in the tank of the electrostatic coalescence secondary separator 11, and the internal boundary position of the tank of the electrostatic coalescence secondary separator 11 is controlled by the electric stripping booster pump 14 through a frequency converter. The pressure in the electric dehydrator 12 tank is controlled by a hot flow outlet control valve of the qualified crude oil/water-containing crude oil heat exchanger 7, and the oil-water interface is controlled by a water outlet control valve.
Further, a water source well water supplementing pipeline is arranged at the inlet of the production water buffer tank 18, and the liquid level of the production water buffer tank 18 is controlled by a water source well water supplementing pipeline control valve and a production water back mixing pump 20 outlet control valve. The outlet flow rate of the power fluid injection pump 23 is regulated by the reflux production water buffer tank 18.
Further, the well mouth is injected with preservative, and the outlets of the metering manifold 1, the open-flow manifold 2 and the production manifold 3 are injected with antiscaling agent, demulsifier and defoaming agent.
Further, sand washing pipelines are arranged at the bottoms of the electrostatic coalescence primary separator 9, the electrostatic coalescence secondary separator 11 and the electric dehydrator 12.
When the electric submersible pump is used for oil extraction, the power fluid booster pump pre-filter 21, the power fluid booster pump 22, the power fluid injection pump 23 and the power fluid injection manifold 24 do not need to be arranged, and meanwhile, the pipeline of the outlet of the production water buffer tank 18 to the power fluid booster pump pre-filter 21 is removed.
The foregoing embodiments are only for illustrating the present invention, wherein the structures, connection modes, manufacturing processes, etc. of the components may be changed, and all equivalent changes and modifications performed on the basis of the technical solutions of the present invention should not be excluded from the protection scope of the present invention.
Claims (10)
1. A marine thermal recovery thick oil gathering and transportation treatment process package comprises a metering manifold, a jet flow manifold, a production manifold, a jet flow tank, a qualified crude oil/water-containing crude oil heat exchanger, an electrostatic coalescence primary separator, an electrostatic coalescence secondary separator and an electric dehydrator;
The metering manifold, the open flow manifold and the production manifold are all connected with a thermal production wellhead production tree, wherein the metering manifold is connected with a metering separator through a metering heater, the open flow manifold is connected with an anti-spraying tank, and a liquid phase outlet of the metering separator, a liquid phase outlet of the open flow tank and the production manifold are all connected with a cold flow inlet of the qualified crude oil/water-containing crude oil heat exchanger;
The cold flow outlet of the qualified crude oil/water-containing crude oil heat exchanger is sequentially connected with a first production heater, the electrostatic coalescence primary separator, a second production heater and the electrostatic coalescence secondary separator; the oil phase outlet of the electrostatic coalescence secondary separator is sequentially connected with the pre-electric dewatering pump filter and the electric dewatering booster pump, the outlet of the electric dewatering booster pump is connected with the inlet of the electric dewatering device, the water phase outlet of the electric dewatering device is connected with the inlet of the cyclone sand remover, the oil phase outlet is connected with the heat flow inlet of the qualified crude oil/water-containing crude oil heat exchanger, and qualified crude oil produced by the heat flow outlet of the qualified crude oil/water-containing crude oil heat exchanger is transported outwards through the pump or stored after being cooled;
And the water phase outlets of the electrostatic coalescence primary separator, the electrostatic coalescence secondary separator and the electric dehydrator are connected with a post-dewatering treatment system of the cyclone sand remover.
2. The process kit of claim 1, wherein: the electrostatic coalescence primary separator and the water phase outlet of the electric dehydrator are directly connected with the inlet of the cyclone sand remover;
and the water phase outlet of the electrostatic coalescence secondary separator is sequentially connected with a secondary back doping pump pre-filter and a secondary back doping pump and then connected with the inlet of the cyclone sand remover.
3. The process kit of claim 2, wherein: the liquid phase outlet of the cyclone sand remover is connected with the inlet of the production water buffer tank, and the solid phase outlet of the cyclone sand remover is connected with the inlet of the sand treatment system;
The outlet of the production water buffer tank is divided into three branches, one branch is connected with a production water back mixing pump through a production water back mixing pump inlet filter, and the outlet of the production water back mixing pump is connected with the inlet of the first production heater; the other branch is connected with an inlet of the power fluid booster pump through a power fluid booster pump inlet filter, an outlet of the power fluid booster pump is connected with an inlet of the power fluid injection pump, an outlet of the power fluid injection pump is connected with an inlet of a power fluid injection manifold, and an outlet of the power fluid injection manifold is connected with a thermal wellhead christmas tree; the third branch is connected with an inlet of the water treatment system.
4. A process kit according to claim 3, wherein: and the gas phase outlets of the open flow tank, the electrostatic coalescence primary separator and the electrostatic coalescence secondary separator are respectively connected with a cold emptying pipeline and a nitrogen maintenance pressure pipeline through pressure control valves.
5. The process kit of claim 4, wherein: and a gas phase outlet pipeline of the metering separator is converged with a liquid phase outlet pipeline and then goes to the qualified oil/water-containing crude oil heat exchanger, meanwhile, a gas phase outlet is also connected with a nitrogen maintenance pressure pipeline, and pressure control valves are arranged at the joints of the gas phase outlet, the nitrogen maintenance pressure pipeline and the liquid phase outlet.
6. The process kit of claim 5, wherein: the liquid level obtained in the electrostatic coalescence primary separator is controlled by a control valve of a water outlet pipeline, and the oil-water interface level is controlled by a control valve of the outlet of the second production heater;
The liquid level in the electrostatic coalescence secondary separator is controlled by a secondary back-doped pump outlet control valve, and the oil-water interface is controlled by adjusting the rotating speed of an electric stripping booster pump through a frequency converter.
7. The process kit of claim 6, wherein: the liquid level of the production water buffer tank is controlled by a water source well water supplementing pipeline control valve and a production water back mixing pump outlet control valve, and the outlet flow of the power liquid injection pump is regulated by the back flow production water buffer tank.
8. The processing system of claim 7, wherein: the electrostatic coalescence primary separator and the electrostatic coalescence secondary separator are used for carrying out oil-gas-water three-phase separation, wherein an insulating electrode is arranged in a liquid phase area, and oil-water separation is promoted by the action of an electric field;
the internal electrode of the electric dehydrator is a bare electrode;
The pressure in the electric dehydrator is controlled by a control valve of a cold flow outlet of the qualified crude oil/water-containing crude oil heat exchanger, and the oil-water interface is controlled by a water phase outlet control valve of the qualified crude oil/water-containing crude oil heat exchanger;
the bottoms of the electrostatic coalescence primary separator, the electrostatic coalescence secondary separator and the dehydrator are all provided with sand washing pipelines.
9. The process kit of claim 8, wherein: the open-flow tank and the metering separator are both vertical tank bodies, and a tipping bucket metering device is arranged in the open-flow tank and the metering separator;
The metering separator is connected with the metering manifold through a bypass pipeline;
And the liquid phase outlets of the open flow tank and the metering separator are provided with control valve positions.
10. The process kit of claim 9, wherein: the outlet of the thermal recovery wellhead Christmas tree is connected with a preservative injection pipeline;
and the outlets of the metering manifold, the open-flow manifold and the production manifold are connected with an anti-scaling agent injection pipeline, a demulsifier injection pipeline and a defoaming agent injection pipeline.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202110942445.1A CN113482586B (en) | 2021-08-17 | 2021-08-17 | Marine thermal recovery viscous crude collection and transportation treatment process package |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202110942445.1A CN113482586B (en) | 2021-08-17 | 2021-08-17 | Marine thermal recovery viscous crude collection and transportation treatment process package |
Publications (2)
| Publication Number | Publication Date |
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