CN113482586A - Offshore thermal recovery thickened oil gathering and transportation treatment process bag - Google Patents
Offshore thermal recovery thickened oil gathering and transportation treatment process bag Download PDFInfo
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- CN113482586A CN113482586A CN202110942445.1A CN202110942445A CN113482586A CN 113482586 A CN113482586 A CN 113482586A CN 202110942445 A CN202110942445 A CN 202110942445A CN 113482586 A CN113482586 A CN 113482586A
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- 238000000034 method Methods 0.000 title claims abstract description 29
- 230000008569 process Effects 0.000 title claims abstract description 27
- 238000011084 recovery Methods 0.000 title claims abstract description 21
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 119
- 238000004519 manufacturing process Methods 0.000 claims abstract description 71
- 238000004581 coalescence Methods 0.000 claims abstract description 64
- 239000010779 crude oil Substances 0.000 claims abstract description 56
- 239000003921 oil Substances 0.000 claims abstract description 43
- 241000191291 Abies alba Species 0.000 claims abstract description 9
- 239000007788 liquid Substances 0.000 claims description 56
- 238000002347 injection Methods 0.000 claims description 34
- 239000007924 injection Substances 0.000 claims description 34
- 238000002156 mixing Methods 0.000 claims description 31
- 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
- 239000004576 sand Substances 0.000 claims description 13
- 239000007789 gas Substances 0.000 claims description 12
- 229910052757 nitrogen Inorganic materials 0.000 claims description 10
- 238000011045 prefiltration Methods 0.000 claims description 8
- 238000000926 separation method Methods 0.000 claims description 6
- 230000005684 electric field 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
- 230000009471 action Effects 0.000 claims description 3
- 239000002518 antifoaming agent Substances 0.000 claims description 3
- 239000003795 chemical substances by application Substances 0.000 claims description 3
- 239000003755 preservative agent Substances 0.000 claims description 3
- 230000002335 preservative effect Effects 0.000 claims description 3
- 238000012545 processing Methods 0.000 claims description 3
- 230000001105 regulatory effect Effects 0.000 claims description 3
- 239000007790 solid phase Substances 0.000 claims description 3
- 238000005191 phase separation Methods 0.000 claims description 2
- 230000002265 prevention Effects 0.000 claims description 2
- 239000007921 spray Substances 0.000 claims 2
- 238000011161 development Methods 0.000 abstract description 8
- 239000000295 fuel oil Substances 0.000 abstract description 7
- 239000012530 fluid Substances 0.000 description 5
- 230000014759 maintenance of location Effects 0.000 description 4
- 230000008859 change Effects 0.000 description 3
- 238000010586 diagram Methods 0.000 description 2
- 238000000605 extraction Methods 0.000 description 2
- 238000003825 pressing Methods 0.000 description 2
- 238000010795 Steam Flooding Methods 0.000 description 1
- 230000033228 biological regulation Effects 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
- 230000000694 effects 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
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
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- 238000004064 recycling Methods 0.000 description 1
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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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Abstract
The invention discloses a process kit for gathering and transporting thick oil in offshore thermal recovery. The offshore thermal recovery thickened oil gathering and transportation treatment process bag has the following structure: the metering manifold, the blowout manifold and the production manifold are all connected with a thermal production wellhead Christmas 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; an oil phase outlet of the electrostatic coalescence secondary separator is sequentially connected with an electric pre-pump filter and an electric de-pressurizing pump, an outlet of the electric de-pressurizing pump is connected with an inlet of the electric dehydrator, an oil phase outlet is connected with a 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 out by a 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 dewatering treatment system behind the cyclone desander. The invention can be widely applied to the technical field of offshore heavy oil thermal recovery development engineering.
Description
Technical Field
The invention relates to a marine thermal recovery thickened oil gathering and transportation treatment process bag, and belongs to the technical field of marine thermal recovery thickened oil development engineering.
Background
The thick oil has high viscosity and high density, and the development modes such as steam huff and puff, steam flooding and the like are often adopted during development, namely, high-temperature and high-pressure steam is injected into the stratum, the viscosity of crude oil in the stratum is reduced through heating, and the thick oil is extracted from the stratum. After the thickened oil is extracted from the stratum, three problems mainly exist in the process treatment, on one hand, the thickened oil is very difficult to dewater due to high viscosity and small oil-water density difference; on the other hand, heavy oil thermal recovery is generally divided into a series of processes such as heat injection, well stewing, open flow and the like, the gas-liquid volume change of the produced fluid is large, the temperature change is large, and particularly, the change is severe at the open flow period; in addition, the thick oil has high sand content, which easily causes the damage of equipment and sea pipes, and the thick oil has high viscosity, so that the sand removing effect of the directly adopted cyclone sand remover for the thick oil is not good. The offshore platform has a very limited area, and is difficult to adopt the processes of large tank sedimentation, buffering and the like on the land, and in order to enable the thick oil thermal collection and transportation treatment process to be smoothly implemented on the sea, a targeted process needs to be developed to deal with the problems.
Disclosure of Invention
The invention aims to provide a marine thermal recovery thickened oil gathering and transportation treatment process kit, which is applied to the technical field of marine thermal recovery development engineering of thickened oil.
The invention provides a marine thermal recovery thickened oil gathering and transportation treatment process bag which comprises a metering manifold, a blowout manifold, a production manifold, a blowout 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, wherein the metering manifold is connected with the production manifold;
the metering manifold, the blowout manifold and the production manifold are all connected with a thermal production wellhead Christmas tree, wherein the metering manifold is connected with a metering separator through a metering heater, the blowout manifold is connected with a blowout prevention tank, and a liquid phase outlet of the metering separator, a liquid phase outlet of the blowout 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 the first production heater, the electrostatic coalescence primary separator, the second production heater and the electrostatic coalescence secondary separator; an oil phase outlet of the electrostatic coalescence secondary separator is sequentially connected with an electric pre-pump filter and an electric de-pressurizing pump, an outlet of the electric de-pressurizing pump is connected with an inlet of an electric dehydrator, a water phase outlet of the electric dehydrator is connected with an inlet of a cyclone desander, an oil phase outlet is connected with a 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 output by a pump or is 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 dewatering treatment system behind the cyclone desander.
Specifically, the water phase outlets of the electrostatic coalescence primary separator and the electric dehydrator are directly connected with the inlet of the cyclone desander;
and a water phase outlet of the electrostatic coalescence secondary separator is sequentially connected with a secondary back-mixing pump pre-filter and a secondary back-mixing pump and then is connected with an inlet of the cyclone desander, and the pressure of the inlet of the cyclone desander is more than or equal to 200 kPaG.
Specifically, a liquid phase outlet of the cyclone desander is connected with an inlet of a production water buffer tank, and a solid phase outlet of the cyclone desander 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 the 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 liquid booster pump through an inlet filter of the power liquid booster pump, an outlet of the power liquid booster pump is connected with an inlet of a power liquid injection pump, an outlet of the power liquid injection pump is connected with an inlet of a power liquid injection manifold, and an outlet of the power liquid injection manifold is connected with a thermal recovery wellhead Christmas tree; the third branch is connected with the inlet of the water treatment system.
Specifically, gas phase outlets of the blow-off tank, the electrostatic coalescence primary separator and the electrostatic coalescence secondary separator are respectively connected with a cold blow-off pipeline and a nitrogen pressure maintaining pipeline through pressure control valves, and the two pressure control valves jointly control the pressure in the tank to ensure the stability of the pressure in the tank.
Specifically, a gas phase outlet pipeline and a liquid phase outlet pipeline of the metering separator are converged and then go to the qualified oil/water-containing crude oil heat exchanger, meanwhile, a gas phase outlet is also connected with a nitrogen pressure maintaining pipeline, pressure control valves are arranged at the connection positions of the gas phase outlet and the nitrogen pressure maintaining pipeline and the liquid phase outlet, and the two pressure control valves jointly control the pressure in the metering separator tank.
Specifically, the liquid level within the electrostatic coalescing primary separator is controlled by a control valve of the water outlet line and the oil-water boundary level is controlled by a control valve of the second production heater outlet;
the liquid level in the electrostatic coalescence secondary separator is controlled by a secondary backmixing pump outlet control valve, and the oil-water boundary position is controlled by regulating the rotating speed of the electric de-pressurizing pump through a frequency converter.
Specifically, the liquid level of the production water buffer tank is controlled by a water source well water replenishing pipeline control valve and a production water back-mixing pump outlet control valve together, and the outlet flow of the power liquid injection pump realizes flow regulation through a backflow production water buffer tank.
Specifically, the electrostatic coalescence primary separator and the electrostatic coalescence secondary separator carry out oil-gas-water three-phase separation, wherein an insulating electrode is arranged in a liquid phase region to promote oil-water separation under the action of an electric field, the water content of an oil outlet of the electrostatic coalescence primary separator is about 50-60%, and the operation pressure of the electrostatic coalescence secondary separation is low, generally about 20-200 kPaG;
the internal electrode of the electric dehydrator is a bare electrode, in order to ensure the normal operation of the electric dehydrator, the water content of an inlet is not more than 30 percent, and the water content of outlet crude oil is less than 2 percent, so that the qualified crude oil standard of heavy 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 position 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 blow-out tank and the metering separator both adopt vertical tank bodies, and a tipping bucket metering device is arranged in the blow-out tank and the metering separator for metering the flow of a 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 liquid phase outlets of the blow 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 recovery wellhead Christmas tree is connected with a preservative injection pipeline;
outlets of the metering manifold, the blowout manifold and the production manifold are connected with an anti-scale agent injection pipeline, a demulsifier injection pipeline and a defoaming agent injection pipeline.
In the system, the two-stage back-mixing pump is generally a centrifugal pump, the electric de-supercharging pump is generally a screw pump, filters are arranged in front of the pump for protection, and the pump and the filters are required to be arranged for standby.
The production water back-mixing pump reaches the power liquid booster pump generally adopts the centrifugal pump, all sets up the filter before the pump, and power liquid injection pump adopts the plunger pump more, and pump and filter all need set up for subsequent use.
When the system is used for offshore thermal recovery thickened oil gathering and transportation treatment, the water content of the inlet of the electrostatic coalescence primary separator reaches 80% or above through back-blending production water and water replenishing of the water source well, and the water blending point of the water source well is positioned at the inlet of the production 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-containing 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 the oil extraction mode, when the oil has low viscosity and small density, the electrostatic coalescence insulated electrode in the electrostatic coalescence primary separator can be removed, and no electric field is applied; when the oil well adopts an electric submersible pump instead of a jet pump, a filter before a power liquid booster pump, a power liquid injection pump and a power liquid injection manifold are removed.
Due to the adoption of 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 the well flow, improves the oil-water separation efficiency through the action of an electric field, and ensures the high-efficiency separation of the thickened oil and the water.
2. The invention is provided with the independent blowout manifold, the metering manifold, the blowout tank and the metering separator, and the tipping bucket metering device is arranged in the blowout tank and the metering separator, so that the metering device can adapt to the metering requirement of each development period of the thermal recovery of the heavy oil.
3. The invention solves the difficult problem of sand removal of thick oil on the sea by mixing water and washing sand and separating and removing sand in the production water.
4. The invention sets a power liquid circulating injection process flow, and can realize the recycling of the power liquid when the jet pump is adopted to produce oil.
5. The water content of the crude oil produced by the method can meet the requirement of qualified crude oil, and the whole process treatment of the offshore heavy oil is realized.
6. The invention utilizes high-efficiency treatment equipment, shortens the retention time of oil-gas-water separation, 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 heavy oil thermal recovery development engineering.
Drawings
FIG. 1 is a schematic diagram of an offshore thermal recovery heavy oil gathering and transportation treatment process pack.
Detailed Description
The experimental procedures used in the following examples are all conventional procedures unless otherwise specified.
Materials, reagents and the like used in the following examples are commercially available unless otherwise specified.
The invention is explained by taking a certain thick oil field development process package of Bohai sea as an example, and the oil treatment capacity of the process package is 1909m3And d, adopting a jet pump to recover oil.
As shown in fig. 1, a schematic diagram of a thick oil gathering and transportation processing process kit provided by the present invention includes: the device comprises a metering manifold 1, a blowout manifold 2, a production manifold 3, a blowout tank 4, a metering heater 5, a metering separator 6, a qualified crude oil/water-containing crude oil heat exchanger 7, a first production heater 8, an electrostatic coalescence primary separator 9, a second production heater 10, an electrostatic coalescence secondary separator 11, an electric dehydrator 12, an electric pre-pump filter 13, an electric de-pressurizing pump 14, a secondary pre-pump filter 15, a secondary back-mixing pump 16, a cyclone desander 17, a production water buffer tank 18, a production water pre-pump filter 19, a production water back-mixing pump 20, a power liquid pre-pressurizing pump filter 21, a power liquid pressurizing pump 22, a power liquid injection pump 23 and a power liquid injection manifold 24.
Wherein, the inlets of a metering manifold 1, a blowout manifold 2 and a production manifold 3 are all connected with a thermal production wellhead Christmas tree, the outlet of the metering manifold 1 is connected with the inlet of a metering heater 5, the outlet of the metering heater 5 is connected with the inlet of a metering separator 6, the blowout manifold 2 is connected with the inlet of a blowout tank 4, the liquid outlets of the blowout tank 4, the metering separator 6 and the production manifold 3 are all connected with the cold flow inlet of a 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 a first production heater 8, the cold flow outlet of the first production heater 8 is connected with the inlet of an electrostatic coalescence primary separator 9, the oil outlet of the electrostatic coalescence primary separator 9 is connected with the cold flow inlet of a second production heater 10, the cold flow outlet of the second production heater 10 is connected with the inlet of an electrostatic coalescence secondary separator 11, the oil outlet of the electrostatic coalescence secondary separator 11 is connected with the inlet of a pre-electric pump filter 13, the outlet of the electric pre-pump filter 13 is connected with the inlet of an electric de-pressurizing pump 14, the outlet of the electric de-pressurizing pump 14 is connected with the inlet of an electric dehydrator 12, the oil outlet of the electric dehydrator 12 is connected with the heat flow inlet of a qualified crude oil/water-containing crude oil heat exchanger 7, and the fluid of the heat flow outlet of the qualified crude oil/water-containing crude oil heat exchanger 7 is sent to an external transportation pump or is stored after being cooled.
Further, the blowout tank can bear 1-4 wells and carry out blowout at the same time, the operating temperature is 64-121 ℃, and the operating pressure is 750 kPaG; a skip bucket metering device is arranged in the metering separator, the operating temperature is 70-89.8 ℃, and the operating pressure is 750 kPaG.
Further, the gas outlets of the blowout tank 4, the electrostatic coalescence primary separator 9 and the electrostatic coalescence secondary separator 11 are all connected with a nitrogen maintaining and pressing pipeline and a cold emptying pipeline, and the pressure in the blowout tank 4, the electrostatic coalescence primary separator 9 and the electrostatic coalescence secondary separator 11 is controlled by two pressure control valves at the connection positions of the gas outlets and the nitrogen maintaining and pressing pipeline and the cold emptying pipeline together.
Further, a 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 embodiment, the operation temperature of the first-stage electrostatic coalescence separator 9 is 80 ℃, the operation pressure is 550kPaG, the liquid phase retention time is 40 minutes, and the water content of the liquid phase outlet is 50%; the operation temperature of the electrostatic coalescence secondary separator 11 is 110 ℃, the operation pressure is 140kPaG, the liquid phase retention time is 40 minutes, and the water content of an outlet is 30 percent; the operation temperature of the electric dehydrator is 110 ℃, the operation pressure is 550kPaG, the liquid phase retention time is 60 minutes, the mass water content of the outlet crude oil is less than or equal to 2 percent, and the requirement of the relevant water content of qualified heavy thick oil is met.
Further, the water outlet of the electrostatic coalescence primary separator 9 is connected with the inlet of a cyclone desander 17, the water outlet of the electrostatic coalescence secondary separator 11 is connected with the inlet of a secondary back-blending pump front filter 15, the outlet of the secondary back-blending pump front filter 15 is connected with the inlet of a secondary back-blending pump 16, the outlet of the secondary back-blending pump 16 is connected with the inlet of the cyclone desander 17, and the water outlet of the electric dehydrator 12 is connected with the inlet of the cyclone desander 17. The liquid phase outlet of the cyclone desander 17 is connected with the inlet of a 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 a 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; and the last path is connected with a power liquid booster pump pre-filter 21, the outlet of the power liquid booster pump pre-filter 21 is connected with the inlet of a power liquid booster pump 22, the outlet of the power liquid booster pump 22 is connected with the inlet of a power liquid injection pump 23, the outlet of the power liquid injection pump 23 is connected with the inlet of a power liquid injection manifold 24, and the outlet of the power liquid injection manifold 24 is connected with a thermal recovery wellhead Christmas tree. The solid phase outlet of the cyclone desander 17 is connected with the inlet of the sand treatment system.
Further, in the embodiment, the power liquid injection pump 23 adopts 4 devices and 1 device, and the flow rate of each device is 40 square/hour; the produced water back-mixing water pump 2 uses 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 water mixing can reach 80 percent or more.
Further, a water outlet control valve of the electrostatic coalescence primary separator 9 controls the liquid level in the tank, and an 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-mixing pump 16 controls the liquid level in the tank of the electrostatic coalescence secondary separator 11, and the internal boundary level of the tank of the electrostatic coalescence secondary separator 11 is controlled by the electric de-pressurizing pump 14 through a frequency converter. The pressure in the electric dehydrator 12 is controlled by a heat flow outlet control valve of the qualified crude oil/water-containing crude oil heat exchanger 7, and the oil-water interface position is controlled by a water outlet control valve.
Furthermore, a water source well water replenishing 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 replenishing pipeline control valve and a production water back-mixing pump 20 outlet control valve together. The outlet flow of the power liquid injection pump 23 is regulated by the return production water buffer tank 18.
And further, injecting a preservative at the wellhead, and injecting an anti-scaling agent, a demulsifier and a defoaming agent at the outlets of the metering manifold 1, the open flow manifold 2 and the production manifold 3.
Furthermore, 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 liquid booster pump pre-filter 21, the power liquid booster pump 22, the power liquid injection pump 23 and the power liquid injection manifold 24 do not need to be arranged, and meanwhile, pipelines from the outlet of the production water buffer tank 18 to the power liquid booster pump pre-filter 21 are removed.
The above embodiments are only used for illustrating the present invention, and the structure, connection mode, manufacturing process, etc. of the components may be changed, and all equivalent changes and modifications performed on the basis of the technical solution of the present invention should not be excluded from the protection scope of the present invention.
Claims (10)
1. A marine thermal recovery thickened oil gathering and transportation processing process pack comprises a metering manifold, a blowout manifold, a production manifold, a blowout 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 blowout manifold and the production manifold are all connected with a thermal production wellhead Christmas tree, wherein the metering manifold is connected with a metering separator through a metering heater, the blowout manifold is connected with a blowout prevention tank, and a liquid phase outlet of the metering separator, a liquid phase outlet of the blowout 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 the first production heater, the electrostatic coalescence primary separator, the second production heater and the electrostatic coalescence secondary separator; an oil phase outlet of the electrostatic coalescence secondary separator is sequentially connected with an electric pre-pump filter and an electric de-pressurizing pump, an outlet of the electric de-pressurizing pump is connected with an inlet of an electric dehydrator, a water phase outlet of the electric dehydrator is connected with an inlet of a cyclone desander, an oil phase outlet is connected with a 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 output by a pump or is 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 dewatering treatment system behind the cyclone desander.
2. The process kit of claim 1, wherein: the water phase outlets of the electrostatic coalescence primary separator and the electric dehydrator are directly connected with the inlet of the cyclone desander;
and a water phase outlet of the electrostatic coalescence secondary separator is connected with a secondary back-mixing pump pre-filter and a secondary back-mixing pump in sequence and then is connected with an inlet of the cyclone desander.
3. The process kit of claim 2, wherein: the liquid phase outlet of the cyclone desander is connected with the inlet of the production water buffer tank, and the solid phase outlet of the cyclone desander 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 the 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 liquid booster pump through an inlet filter of the power liquid booster pump, an outlet of the power liquid booster pump is connected with an inlet of a power liquid injection pump, an outlet of the power liquid injection pump is connected with an inlet of a power liquid injection manifold, and an outlet of the power liquid injection manifold is connected with a thermal recovery wellhead Christmas tree; the third branch is connected with the inlet of the water treatment system.
4. The process kit of any one of claims 1-3, wherein: and gas phase outlets of the blow-off tank, the electrostatic coalescence primary separator and the electrostatic coalescence secondary separator are respectively connected with a cold blow-off pipeline and a nitrogen pressure maintaining pipeline through pressure control valves.
5. The process kit of any one of claims 1-4, wherein: and a gas phase outlet pipeline and a liquid phase outlet pipeline of the metering separator are converged and then go to the qualified oil/water-containing crude oil heat exchanger, meanwhile, a gas phase outlet is also connected with a 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.
6. The process kit of any one of claims 1-5, wherein: the liquid level in the electrostatic coalescence primary separator is controlled by a control valve of a water outlet pipeline, and the oil-water boundary 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 backmixing pump outlet control valve, and the oil-water boundary position is controlled by regulating the rotating speed of the electric de-pressurizing pump through a frequency converter.
7. The process kit of any one of claims 3-6, wherein: the liquid level of the production water buffer tank is controlled by a water source well water replenishing pipeline control valve and a production water back-mixing pump outlet control valve together, and the flow of the outlet of the power liquid injection pump is adjusted by the back-flow production water buffer tank.
8. The processing system according to any one of claims 1 to 7, wherein: 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 region, and oil-water separation is promoted through the action of an electric field;
the inner electrode of the electric dehydrator is a bare electrode;
the pressure in the electric dehydrator is controlled by a control valve at a cold flow outlet of the qualified crude oil/water-containing crude oil heat exchanger, and an oil-water interface is controlled by a control valve at a water phase outlet of the qualified crude oil/water-containing crude oil heat exchanger;
and sand washing pipelines are arranged at the bottoms of the electrostatic coalescence primary separator, the electrostatic coalescence secondary separator and the dehydrator.
9. The process kit of any one of claims 1 to 8, wherein: the discharge and spray tank and the metering separator both adopt vertical tank bodies, and a tipping bucket metering device is arranged in the discharge and spray tank and the metering separator;
the metering separator is connected with the metering manifold through a bypass pipeline;
and control valve positions are arranged at the liquid phase outlets of the blow tank and the metering separator.
10. The process kit of any one of claims 1 to 9, wherein: the outlet of the thermal recovery wellhead Christmas tree is connected with a preservative injection pipeline;
and 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)
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