CN108728197A - A kind of oil field accompanying gas recovering device and method - Google Patents
A kind of oil field accompanying gas recovering device and method Download PDFInfo
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- CN108728197A CN108728197A CN201810885482.1A CN201810885482A CN108728197A CN 108728197 A CN108728197 A CN 108728197A CN 201810885482 A CN201810885482 A CN 201810885482A CN 108728197 A CN108728197 A CN 108728197A
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- 238000000034 method Methods 0.000 title claims abstract description 34
- 239000002002 slurry Substances 0.000 claims abstract description 82
- 238000006703 hydration reaction Methods 0.000 claims abstract description 63
- 238000004519 manufacturing process Methods 0.000 claims abstract description 62
- 238000005057 refrigeration Methods 0.000 claims abstract description 53
- 239000007788 liquid Substances 0.000 claims abstract description 35
- 238000000926 separation method Methods 0.000 claims abstract description 30
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 27
- 238000012544 monitoring process Methods 0.000 claims abstract description 26
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 23
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 23
- 238000012545 processing Methods 0.000 claims abstract description 22
- 230000008569 process Effects 0.000 claims abstract description 11
- 239000007789 gas Substances 0.000 claims description 124
- 239000012530 fluid Substances 0.000 claims description 65
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 42
- 239000010410 layer Substances 0.000 claims description 30
- 230000002194 synthesizing effect Effects 0.000 claims description 24
- 230000008859 change Effects 0.000 claims description 22
- 239000003345 natural gas Substances 0.000 claims description 20
- 230000015572 biosynthetic process Effects 0.000 claims description 15
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 13
- 238000011835 investigation Methods 0.000 claims description 11
- 238000013528 artificial neural network Methods 0.000 claims description 10
- 210000004027 cell Anatomy 0.000 claims description 9
- 230000036571 hydration Effects 0.000 claims description 9
- 238000006243 chemical reaction Methods 0.000 claims description 8
- 238000004088 simulation Methods 0.000 claims description 8
- 238000005516 engineering process Methods 0.000 claims description 7
- 210000002569 neuron Anatomy 0.000 claims description 7
- 238000011084 recovery Methods 0.000 claims description 7
- 239000003507 refrigerant Substances 0.000 claims description 7
- 230000000740 bleeding effect Effects 0.000 claims description 6
- 230000005284 excitation Effects 0.000 claims description 6
- 238000007726 management method Methods 0.000 claims description 6
- 238000005086 pumping Methods 0.000 claims description 6
- 230000035484 reaction time Effects 0.000 claims description 6
- 238000010079 rubber tapping Methods 0.000 claims description 6
- NUXZAAJDCYMILL-UHFFFAOYSA-K trichlorolanthanum;hydrate Chemical compound O.Cl[La](Cl)Cl NUXZAAJDCYMILL-UHFFFAOYSA-K 0.000 claims description 6
- 238000012549 training Methods 0.000 claims description 4
- 241001269238 Data Species 0.000 claims description 3
- 238000001914 filtration Methods 0.000 claims description 3
- 239000012535 impurity Substances 0.000 claims description 3
- 239000011229 interlayer Substances 0.000 claims description 3
- 230000006911 nucleation Effects 0.000 claims description 3
- 238000010899 nucleation Methods 0.000 claims description 3
- 238000012546 transfer Methods 0.000 claims description 3
- 238000013461 design Methods 0.000 abstract description 5
- 230000006872 improvement Effects 0.000 abstract description 5
- 150000004677 hydrates Chemical class 0.000 abstract description 4
- -1 supercharging Substances 0.000 abstract description 3
- 238000009434 installation Methods 0.000 abstract description 2
- 239000002699 waste material Substances 0.000 abstract description 2
- 238000010586 diagram Methods 0.000 description 3
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 3
- 239000012071 phase Substances 0.000 description 3
- 241000208340 Araliaceae Species 0.000 description 2
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- 235000005035 Panax pseudoginseng ssp. pseudoginseng Nutrition 0.000 description 2
- 235000003140 Panax quinquefolius Nutrition 0.000 description 2
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 2
- 238000001816 cooling Methods 0.000 description 2
- 235000008434 ginseng Nutrition 0.000 description 2
- 125000001183 hydrocarbyl group Chemical group 0.000 description 2
- 239000003949 liquefied natural gas Substances 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- NMJORVOYSJLJGU-UHFFFAOYSA-N methane clathrate Chemical compound C.C.C.C.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O NMJORVOYSJLJGU-UHFFFAOYSA-N 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000004064 recycling Methods 0.000 description 2
- 238000003786 synthesis reaction Methods 0.000 description 2
- 238000004148 unit process Methods 0.000 description 2
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 1
- 150000001335 aliphatic alkanes Chemical class 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000001273 butane Substances 0.000 description 1
- 239000000470 constituent Substances 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 230000008676 import Effects 0.000 description 1
- 238000009413 insulation Methods 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 1
- 239000001294 propane Substances 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 230000031068 symbiosis, encompassing mutualism through parasitism Effects 0.000 description 1
- 238000012384 transportation and delivery Methods 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
- C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
- C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
- C10L3/10—Working-up natural gas or synthetic natural gas
- C10L3/101—Removal of contaminants
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- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Engineering & Computer Science (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Organic Chemistry (AREA)
- Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
- Physical Or Chemical Processes And Apparatus (AREA)
Abstract
The present invention relates to a kind of oil field accompanying gas recovering device and methods, belong to gas hydrates applied technical field.By cold catch pot Structure Improvement Design, associated gas enters cold catch pot after primary separation, sub-cooled and realizes heavy hydrocarbon multi-segment removing；The first refrigeration system, the second refrigeration system are designed, adjusted by data monitoring unit and controls each pipeline cryogen flow；In conjunction with site technique, integrated de- heavy hydrocarbon, supercharging, liquid storage, hydration reaction, the hydrate skid process units that defeated processing and refrigeration unit are integrated outside hydrate slurry.A kind of oil field accompanying gas recovering device and method provided through the invention, associated gas is changed into hydrate, can realize that the removing of associated gas heavy hydrocarbon, hydrate are quickly prepared, hydrate generating rate calculates and the functions such as production quantity control, can effectively solve part do not have piping facility or be unworthy that the associated gas in the outlying oil field of pipeline installation is difficult to recycle and caused by problem of resource waste.
Description
Technical field
The present invention relates to a kind of oil field accompanying gas recovering device and methods, belong to gas hydrates applied technical field.
Background technology
Associated gas is also known as casing-head gas, is often referred to the natural gas with oil symbiosis, and main component is that methane, ethane etc. are low
Molecule alkane, also a certain number of propane, butane, pentane etc..Well layout is disperseed, the wide oil field association in distributed areas
Gas, since pipeline investment is larger, it is more difficult to be laid with, the difficulty recycled is very big, develops the defeated gas supply scheme of non-pipe, undoubtedly right
Oil gas field improves associated gas yield, energy-saving and emission-reduction have greatly help.
Currently, the main defeated gas supply scheme of non-pipe mainly has two kinds of compressed natural gas (CNG) and liquefied natural gas (LNG).
Still further aspect carries out natural gas as the research of gas hydrates (NGH) the relevant technologies is gradually ripe using NGH technologies
Storage and transportation can not only greatly reduce natural gas volume, but also solid storage and transportation method has prodigious convenience, be carried for natural gas storage and transportation
New way is supplied.
For NGH technologies to the of less demanding of production equipment, production cost is low, and the condition of storage is opposite to be easier to realize, is being hydrated
The equipment of natural gas-storing need not bear high pressure under object state, and the thermal conductivity of NGH itself is 18.7W/ (m DEG C), than one
As heat-barrier material ((m DEG C) Zuo You of 27W/) it is also low, be not required to special insulation, storage tank can be manufactured with common iron, right
Material requirements is not high, and it is relatively highest to store with safety in transportational process, fully shows gas hydrates
Development potentiality and attractive prospect.
Therefore, in conjunction with hydrate, a kind of oil field accompanying gas recovering device and method is designed, realizes different production run works
The economical and efficient recycling of associated gas under condition, for improving oil gas field associated gas yield, environmental protection has important reality
Meaning.
Invention content
The purpose of the present invention is to provide a kind of oil field accompanying gas recovering device and method, for recycle it is scattered, remote and
The smaller casing-head gas of tolerance, the associated gas for solving remote segment oil field are difficult to recycle and cause a large amount of problem of resource waste.It should
Device can realize that import associated gas purified treatment, hydrate quickly generate and the control of hydrate production quantity, ensure water
Object synthetic reaction is closed smoothly, efficiently to carry out.
Present invention mainly solves following problems：
(1) by cold catch pot Structure Improvement Design, associated gas enters low temperature after primary separation, sub-cooled
Separator carries out heavy hydrocarbon primary removing through S types baffle plate, collecter ring, heavy hydrocarbon three is completed in the first, second, third disengagement chamber
Section removing.
(2) refrigeration unit designs the first refrigeration system, the second refrigeration system, is adjusted and is controlled each by data monitoring unit
Cryogen flow in pipeline provides enough colds for heavy hydrocarbon removal unit, hydration reaction unit.
(3) produced on-site technique is combined, de- heavy hydrocarbon, supercharging, liquid storage, hydration reaction, defeated processing outside hydrate slurry are integrated
And the skid-mounted device that refrigeration unit is integrated, realize continuous, economic, the efficient production of hydrate.
(4) a kind of associated gas recovery method is designed, associated gas is changed into hydrate, can realize that associated gas heavy hydrocarbon is de-
Remove, hydrate is quickly prepared, hydrate generating rate calculate and production quantity control etc. functions.
To achieve the goals above, technical scheme is as follows.
A kind of oil field accompanying gas recovering device includes de- heavy hydrocarbon unit 1, compress cell 2, liquid storage unit 3, hydration reaction list
Defeated processing unit 5, refrigeration unit 6, first flowmeter 7, data monitoring unit 8 outside member 4, hydrate slurry；
The de- heavy hydrocarbon unit 1 includes associated gas air inlet pipe 9, initial separator 10, the first oil exit pipe 11, first exhaust
Pipe 12, heat exchanger 13, refrigerant pipe 14, second exhaust pipe 15, cold catch pot 16, the second oil exit pipe 17, third exhaust pipe 18；
The compress cell 2 includes filter 19, supercharging device 20, second flowmeter 21, the 4th exhaust pipe 22；
The initial separator 10 is connect with associated gas air inlet pipe 9, the first oil exit pipe 11, downtake pipe 12, described
Heat exchanger 13 connect with downtake pipe 12, second exhaust pipe 15, connect with refrigeration unit 6 by refrigerant pipe 14, it is described
Cold catch pot 16 is connect with second exhaust pipe 15, the second oil exit pipe 17, third exhaust pipe 18, the third exhaust pipe 18 according to
It is secondary to be connect with filter 19, supercharging device 20, second flowmeter 21, the 4th exhaust pipe 22, the hydration reaction unit 4 and
Defeated processing unit 5, refrigeration unit 6 connect outside four exhaust pipes 22, hydrate slurry, are connected by first flowmeter 7 and liquid storage unit 3
It connects, the data monitoring unit 8 is to defeated processing unit 5, refrigeration unit 6, first outside hydration reaction unit 4, hydrate slurry
Flowmeter 7, second flowmeter 21 are monitored.
Further, the cold catch pot 16 include the first air inlet 34, S types baffle plate 35, the second air inlet 36,
Collecter ring 37, the first disengagement chamber 38, the second disengagement chamber 39, third disengagement chamber 40, separation exhaust outlet 41,42, first points of drain pipe
Go out from steering ring 43, the first gas outlet 44, the first liquid outlet 45, second separation steering ring 46, second exhaust port 47, second
Liquid mouth 48, third detach steering ring 49；
The cold catch pot 16 divides for upper and lower two chambers, and the lower chambers are equipped with the first air inlet 34, S types
Baffle plate 35, the second air inlet 36, second air inlet 36 are equipped with collecter ring 37, and the upper chamber includes the first separation
Chamber 38, the second disengagement chamber 39, third disengagement chamber 40, first disengagement chamber 38 are equipped with the first separation steering ring 43, first
Gas outlet 44, the first liquid outlet 45, second disengagement chamber 39 be equipped with second separation steering ring 46, second exhaust port 47,
Second liquid outlet 48, the third disengagement chamber 40 are equipped with third separation steering ring 49, separation exhaust outlet 41, drain pipe 42.
Further, well site low pressure linkage type pumping device, inner compressor of standing can be used in the supercharging device 20.
Further, it is characterised in that：The liquid storage unit 3 is set at 1.2~2m of earth's surface or less.
Further, 4 mounting height of hydration reaction unit is 3~7m.
Further, 5 mounting height of defeated processing unit is 3~7m outside the hydrate slurry.
Further, the refrigeration unit 6 include the first refrigeration system 23, it is the second refrigeration system 24, compressor 25, cold
But device 26, surge tank 27；
The compressor 25, cooler 26, surge tank 27 are sequentially connected, the surge tank 27 respectively with the first refrigeration
System 23, the second refrigeration system 24 connection, first refrigeration system 23 include flow control valve 28, first throttle valve 29,
Second surge tank 30, air bleeding valve 31, tapping valve 32, the flow control valve 28, first throttle valve 29, heat exchanger 13, second
Surge tank 30 is sequentially connected, and second surge tank 30 is connect with air bleeding valve 31, tapping valve 32, second refrigeration system
24 include second throttle 33, and the second throttle 33 is connect with hydration reaction unit 4.
Further, a kind of associated gas recovery method, includes the following steps；
S1, associated gas remove heavy hydrocarbon
Associated gas into initial separator 10 just detach through associated gas air inlet pipe 9, and the impurity of separation is through first
Oil exit pipe 11 is discharged, and gas phase enters cold catch pot 16 through downtake pipe 12, heat exchanger 13, second exhaust pipe 15 and carries out heavy hydrocarbon
Removing；
S2, associated gas pressurizing
Associated gas after removing heavy hydrocarbon is increased after the filtering of filter 19 into supercharging device 20 through third exhaust pipe 18
Pressure enters hydration reaction unit 4 after the metering of second flowmeter 21 through the 4th exhaust pipe 22；
S3, associated gas synthesized hydrate slurry
The cold fluid that second throttle 33 comes out enters hydration reactor interlayer and provides cold, fluid reservoir 3 for hydration reaction
Interior water enters hydration reaction unit 4, carries out hydration reaction with associated gas after supercharged, data monitoring unit 8 is collected from the
Flow meters 7, second flowmeter 21, hydration reaction unit 4, defeated processing unit 5 outside hydrate slurry, refrigeration unit 6 temperature,
The related datas such as pressure, flow generate control method using hydrate and carry out production run state modulator；
S4, hydrate slurry working process
Hydrate slurry enters defeated processing unit 5 outside hydrate slurry from hydration reactor 4 and is carried out dehydrating, and removing is big
The slurry of part water enters outer defeated system.
Further, the hydrate described in step S3 generates control method and includes the following steps；
K1, hydrate thermodynamical model is established, carries out Investigation On The Hydrate Formation Conditions prediction
K11, selection predicts that the state equation of Investigation On The Hydrate Formation Conditions, input gas component complete stream in PVTsim softwares
Body packet is established；
K12, selection Investigation On The Hydrate Formation Conditions prediction module, predict the formation temperature condition of hydrate under different pressures, and
Export fluid packet；
K13, change gas component, complete the Investigation On The Hydrate Formation Conditions prediction of gas with various component, and complete fluid packet
Export；
K2, establish hydrate kinetic model, carry out hydrate nucleation, growth simulation, predict hydrate generating rate,
Production quantity and hydrate slurry fluid viscosity
K21, similar pipeline model is established using OLGA softwares according to the specific structure size of hydrate synthesizing device, and
It adds hydrate and generates prediction module；
K22, the fluid packet that PVTsim softwares are established, pressure, the temperature that input hydrate generates are imported in OLGA softwares
Curve data；
K23, the inlet flow rate and temperature that gas-liquid is defined in pipeline starting point, pipeline terminal define the fortune of hydrate synthesizing device
Row pressure, simulate 1h, 2h ..., in Nh in hydrate synthesizing device hydrate generating rate, production quantity and hydrate
Slurry viscosity situation of change；
K24, change liquid-gas ratio, hydrate generating rate, production quantity and hydrate slurry viscosity change in simulator
Situation；
K25, gas-liquid flow, temperature, the pipeline terminal pressure for changing pipeline starting point respectively, repeat step K23, K24, simulation
Under different operating modes in hydrate synthesizing device the generating rate of hydrate, production quantity and hydrate slurry fluid viscosity variation feelings
Condition；
K26, the gas flow by under different operating modes, fluid flow, pressure, temperature and reaction time are stored in input layer pair
The tables of data answered, generating rate, production quantity and the hydrate slurry fluid viscosity deposit output layer of corresponding hydrate correspond to
Tables of data；
Fluid packet in K27, change OLGA softwares inputs the corresponding hydrate of the fluid packet and generates pressure, temperature curve
Data, simulate hydrate generating rate under different component of natural gas, production quantity and hydrate slurry fluid viscosity situation of change；
K28, step K23, K24, K25 are repeated, completes different component of natural gas under different operating modes in hydrate synthesizing device
The situation of change simulation of the generating rate, production quantity and hydrate slurry fluid viscosity of hydrate, while repeating step K26 and completing number
According to statistics；
K3, BP neural network is established, the prediction for forming hydrate generating rate, production quantity and hydrate slurry fluid viscosity is public
Formula
K31, a feedforward BP neural network with hidden layer, packet are established using MATLAB artificial neural networks tool box
Include input layer, middle layer, output layer 3-tier architecture, wherein input layer include gas flow, fluid flow, hydration reaction pressure,
5 neurons of temperature and reaction time, output layer include hydrate generating rate, production quantity and hydrate slurry fluid viscosity 3
A neuron；
K32, input layer data corresponding with output layer are directed respectively into, select suitable excitation function, complete artificial neuron
Network training is converted to hydrate generating rate, hydrate production quantity and hydration by weights, threshold values and excitation function
The predictor formula of object slurry viscosity；
K33, step K32 is repeated, speed, production quantity and hydrate slurry fluid viscosity is generated to the hydrate of gas with various component
It is trained, learns, obtain the hydrate generating rate of gas with various component, the prediction public affairs of production quantity and hydrate slurry fluid viscosity
Formula；
K4, by calculating above, in conjunction with hydrate monitoring management system, carry out lanthanum chloride hydrate technology controlling and process management
K41 input natural gas gas component, hydrate generating rate minimum allowable value, water on hydration reaction monitoring panel
Object slurry viscosity maximum permissible value, maximum allowble pressure, minimum permissible temperature are closed, hydration reaction monitoring system recalls component of natural gas
Closest hydration reaction predictor formula calculates under different gas flow, fluid flow, reaction temperature, reaction pressure not
With the generating rate of hydrate, hydrate production quantity and hydrate slurry fluid viscosity in the time；
Hydrate is given birth in the data selection prediction result that K42, hydration reaction monitoring system are measured according to natural gas flowmeter
It is manufacturing parameter at the maximum data of rate, controls the liquid inlet volume, pressure and temperature of hydrate synthesizing device；
K43, the pressure according to hydrate synthesizing device, temperature variations, hydration reaction monitoring system real-time display water
Object generating rate, production quantity and hydrate slurry fluid viscosity are closed, and optimal ginseng is chosen according to hydrate generating rate maximum principle
Number adjusts the manufacturing parameter of hydrate synthesizing device；
K44, the time that hydrate tinning is carried out according to amount of capacity, the hydrate production quantity of prediction of hydrate transfer cask
Control.Invention has the beneficial effects that：
(1) present invention is generally directed to not have piping facility or be unworthy scattered, the marginal fields of pipeline installation, design one
Kind oil field accompanying gas recovering device and method realize the economical and efficient recycling of associated gas.
(2) cold catch pot Structure Improvement Design is carried out, is detached by multistage, realizes that the efficient of heavy constituent takes off in gas phase
It removes.
(3) produced on-site technique is combined, de- heavy hydrocarbon, supercharging, liquid storage, hydration reaction, defeated processing outside hydrate slurry are integrated
And the hydrate skid process units that refrigeration unit is integrated, have floor space it is small, it is applied widely, investment operating cost it is low
The features such as.
(4) a kind of associated gas recovery method is designed, associated gas is changed into hydrate slurry, can realize associated gas weight
The functions such as hydrocarbon removing, hydrate are quickly prepared, hydrate generating rate calculates and production quantity controls.
Description of the drawings
Fig. 1 is oil field accompanying gas recovering device schematic diagram in the embodiment of the present invention.
Fig. 2 is associated gas recovery process flow chart in the embodiment of the present invention.
Fig. 3 is refrigeration unit process flow chart in the embodiment of the present invention.
Fig. 4 is cold catch pot front view in the embodiment of the present invention.
Fig. 5 is cold catch pot left view in the embodiment of the present invention.
Fig. 6 is cold catch pot vertical view in the embodiment of the present invention.
Fig. 7 is low pressure linkage type pumping schematic device in well site in the embodiment of the present invention.
Fig. 8 is that associated gas takes off heavy hydrocarbon cell schematics in the embodiment of the present invention.
Fig. 9 is lanthanum chloride hydrate process flow chart in the embodiment of the present invention.
Figure 10 is associated gas lanthanum chloride hydrate cell schematics in the embodiment of the present invention.
Specific implementation mode
The specific implementation mode of the present invention is described below in conjunction with the accompanying drawings, to be better understood from the present invention.
Embodiment
In the present embodiment, Fig. 1 is oil field accompanying gas recovering device schematic diagram in the embodiment of the present invention, and Fig. 2 is of the invention real
Apply associated gas recovery process flow chart in example.Oil field accompanying gas recovering device includes de- heavy hydrocarbon unit 1, compress cell 2, storage
Liquid unit 3, hydration reaction unit 4, defeated processing unit 5, refrigeration unit 6, first flowmeter 7, data monitoring outside hydrate slurry
Unit 8；
The de- heavy hydrocarbon unit 1 includes associated gas air inlet pipe 9, initial separator 10, the first oil exit pipe 11, first exhaust
Pipe 12, heat exchanger 13, refrigerant pipe 14, second exhaust pipe 15, cold catch pot 16, the second oil exit pipe 17, third exhaust pipe 18；
The compress cell 2 includes filter 19, supercharging device 20, second flowmeter 21, the 4th exhaust pipe 22；
The initial separator 10 is connect with associated gas air inlet pipe 9, the first oil exit pipe 11, downtake pipe 12, described
Heat exchanger 13 connect with downtake pipe 12, second exhaust pipe 15, connect with refrigeration unit 6 by refrigerant pipe 14, it is described
Cold catch pot 16 is connect with second exhaust pipe 15, the second oil exit pipe 17, third exhaust pipe 18, the third exhaust pipe 18 according to
It is secondary to be connect with filter 19, supercharging device 20, second flowmeter 21, the 4th exhaust pipe 22, the hydration reaction unit 4 and
Defeated processing unit 5, refrigeration unit 6 connect outside four exhaust pipes 22, hydrate slurry, are connected by first flowmeter 7 and liquid storage unit 3
It connects, the data monitoring unit 8 is to defeated processing unit 5, refrigeration unit 6, first outside hydration reaction unit 4, hydrate slurry
Flowmeter 7, second flowmeter 21 are monitored.
Associated gas is recycled by following steps：
S1, associated gas remove heavy hydrocarbon
Associated gas into initial separator 10 just detach through associated gas air inlet pipe 9, and separation impurity is through the first oil exit pipe
11 discharges, gas phase enter cold catch pot 16 through downtake pipe 12, heat exchanger 13, second exhaust pipe 15 and carry out heavy hydrocarbon removing；
S2, associated gas pressurizing
Associated gas after removing heavy hydrocarbon is increased after the filtering of filter 19 into supercharging device 20 through third exhaust pipe 18
Pressure enters hydration reaction unit 4 after the metering of second flowmeter 21 through the 4th exhaust pipe 22；
S3, associated gas synthesized hydrate slurry
The cold fluid that second throttle 33 comes out enters hydration reactor interlayer and provides cold, fluid reservoir 3 for hydration reaction
Interior water enters hydration reaction unit 4, carries out hydration reaction with associated gas after supercharged, data monitoring unit 8 is collected from the
Flow meters 7, second flowmeter 21, hydration reaction unit 4, defeated processing unit 5 outside hydrate slurry, refrigeration unit 6 temperature,
The related datas such as pressure, flow generate control method using hydrate and carry out production run state modulator；
S4, hydrate slurry working process
Hydrate slurry enters defeated processing unit 5 outside hydrate slurry from hydration reactor 4 and is carried out dehydrating, and removing is big
The slurry of part water enters outer defeated system.
Hydrate described in step S3 generates control method and includes the following steps：
K1, hydrate thermodynamical model is established, carries out Investigation On The Hydrate Formation Conditions prediction
K11, selection predicts that the state equation of Investigation On The Hydrate Formation Conditions, input gas component complete stream in PVTsim softwares
Body packet is established；
K12, selection Hydrate Prediction module, predict the temperature condition of gas hydrate synthesis under different pressures, and export fluid
Packet；
K13, change gas component, complete the Investigation On The Hydrate Formation Conditions prediction of gas with various component, and complete fluid packet
Export；
K2, establish hydrate kinetic model, carry out hydrate nucleation, growth simulation, predict hydrate generating rate,
Production quantity and hydrate slurry fluid viscosity
K21, similar pipeline model is established using OLGA softwares according to the specific structure size of hydrate synthesizing device, and
It adds hydrate and generates prediction module；
K22, the fluid packet that PVTsim softwares are established, pressure, the temperature that input hydrate generates are imported in OLGA softwares
Curve data；
K23, the inlet flow rate and temperature that gas-liquid is defined in pipeline starting point, pipeline terminal define the fortune of hydrate synthesizing device
Row pressure, simulate 1h, 2h ..., in Nh in hydrate synthesizing device hydrate generating rate, production quantity and hydrate
Slurry viscosity situation of change；
K24, change liquid-gas ratio, hydrate generating rate, production quantity and hydrate slurry viscosity change in simulator
Situation；
K25, gas-liquid flow, temperature, the pipeline terminal pressure for changing pipeline starting point respectively, repeat step K23, K24, simulation
Under different operating modes in hydrate synthesizing device the generating rate of hydrate, production quantity and hydrate slurry fluid viscosity variation feelings
Condition；
K26, the gas flow by under different operating modes, fluid flow, pressure, temperature and reaction time are stored in input layer pair
The tables of data answered, generating rate, production quantity and the hydrate slurry fluid viscosity deposit output layer of corresponding hydrate correspond to
Tables of data；
Fluid packet in K27, change OLGA softwares inputs the corresponding hydrate of the fluid packet and generates pressure, temperature curve
Data, simulate hydrate generating rate under different component of natural gas, production quantity and hydrate slurry fluid viscosity situation of change；
K28, step K23, K24, K25 are repeated, completes different component of natural gas under different operating modes in hydrate synthesizing device
The situation of change of hydrate generating rate, production quantity and hydrate slurry fluid viscosity is simulated, while being repeated step K26 and being completed data system
Meter；
K3, BP neural network is established, the prediction for forming hydrate generating rate, production quantity and hydrate slurry fluid viscosity is public
Formula
K31, a feedforward BP neural network with hidden layer, packet are established using MATLAB artificial neural networks tool box
Include input layer, middle layer, output layer 3-tier architecture, wherein input layer include gas flow, fluid flow, hydration reaction pressure,
5 neurons of temperature and reaction time, output layer include hydrate generating rate, production quantity and hydrate slurry fluid viscosity 3
A neuron；
K32, input layer data corresponding with output layer are directed respectively into, select suitable excitation function, complete artificial neuron
Network training is converted to hydrate generating rate, hydrate production quantity and hydration by weights, threshold values and excitation function
The predictor formula of object slurry viscosity；
K33, step K32 is repeated, speed, production quantity and hydrate slurry fluid viscosity is generated to the hydrate of gas with various component
It is trained, learns, obtain the hydrate generating rate of gas with various component, the prediction public affairs of production quantity and hydrate slurry fluid viscosity
Formula.
K4, by calculating above, in conjunction with hydrate monitoring management system, carry out lanthanum chloride hydrate technology controlling and process management
K41 input natural gas gas component, hydrate generating rate minimum allowable value, water on hydration reaction monitoring panel
Object slurry viscosity maximum permissible value, maximum allowble pressure, minimum permissible temperature are closed, hydration reaction monitoring system recalls component of natural gas
Closest hydration reaction predictor formula calculates under different gas flow, fluid flow, reaction temperature, reaction pressure not
With the generating rate of hydrate, hydrate production quantity and hydrate slurry fluid viscosity in the time；
Hydrate is given birth in the data selection prediction result that K42, hydration reaction monitoring system are measured according to natural gas flowmeter
It is manufacturing parameter at the maximum data of rate, controls the liquid inlet volume, pressure and temperature of hydrate synthesizing device；
K43, the pressure according to hydrate synthesizing device, temperature variations, hydration reaction monitoring system real-time display water
Object generating rate, production quantity and hydrate slurry fluid viscosity are closed, and optimal ginseng is chosen according to hydrate generating rate maximum principle
Number adjusts the manufacturing parameter of hydrate synthesizing device；
K44, the time that hydrate tinning is carried out according to amount of capacity, the hydrate production quantity of prediction of hydrate transfer cask
Control.
Fig. 3 is refrigeration unit process flow chart in the embodiment of the present invention, and refrigeration unit 6 includes the first refrigeration system 23, the
Two refrigeration systems 24, compressor 25, cooler 26, surge tank 27；
The compressor 25, cooler 26, surge tank 27 are sequentially connected, the surge tank 27 respectively with the first refrigeration
System 23, the second refrigeration system 24 connection, first refrigeration system 23 include flow control valve 28, first throttle valve 29,
Second surge tank 30, air bleeding valve 31, tapping valve 32, the flow control valve 28, first throttle valve 29, heat exchanger 13, second
Surge tank 30 is sequentially connected, and second surge tank 30 is connect with air bleeding valve 31, tapping valve 32, second refrigeration system
24 include second throttle 33, and the second throttle 33 is connect with hydration reaction unit 4.
In refrigeration unit, gas is entered surge tank 27 after the supercharging of compressor 25 after the cooling of cooler 26, and surge tank goes out
The gas come partly enters the first refrigeration system 23 after the adjusting of flow control valve 28, partly enters the second refrigeration system 24.The
In one refrigeration system 23, gas provides cold after the throttling of first throttle valve 29 for heat exchanger 13, in the second refrigeration system 24
Gas mixed with the refrigerant from the first refrigeration system 23 after through 33 throttling refrigeration of second throttle, be hydration reaction unit 4
Cold is provided.
Fig. 4~Fig. 6 is cold catch pot front view, left view, vertical view in the embodiment of the present invention respectively.Cold catch pot
16 include the first air inlet 34, S types baffle plate 35, the second air inlet 36, collecter ring 37, the first disengagement chamber 38, the second disengagement chamber
39, third disengagement chamber 40, separation exhaust outlet 41, the separation of drain pipe 42, first steering ring 43, the first gas outlet 44, first go out
Liquid mouth 45, second detaches steering ring 46, second exhaust port 47, the second liquid outlet 48, third and detaches steering ring 49；
The cold catch pot 16 divides for upper and lower two chambers, and the lower chambers are equipped with the first air inlet 34, S types
Baffle plate 35, the second air inlet 36, second air inlet 36 are equipped with collecter ring 37, and the upper chamber includes the first separation
Chamber 38, the second disengagement chamber 39, third disengagement chamber 40, first disengagement chamber 38 are equipped with the first separation steering ring 43, first
Gas outlet 44, the first liquid outlet 45, second disengagement chamber 39 be equipped with second separation steering ring 46, second exhaust port 47,
Second liquid outlet 48, the third disengagement chamber 40 are equipped with third separation steering ring 49, separation exhaust outlet 41, drain pipe 42.
Associated gas after cooling initially enters the lower chambers of cold catch pot 16, is carried out through S types baffle plate 35, collecter ring 37
Then primary cryogenic separation passes sequentially through the first disengagement chamber 38, the second disengagement chamber 39, third disengagement chamber 40, led through the first separation
To loop 43, second detaches steering ring 46, third separation steering ring 49 completes three sections of removings of heavy hydrocarbon, liquid phase is through drain pipe 42
Discharge removes the associated gas after heavy hydrocarbon and is discharged through detaching exhaust outlet 41.
Fig. 7 is low pressure linkage type pumping schematic device in well site in the embodiment of the present invention.Supercharging device 20 is raw according to scene
The difference of production. art and different from, may be used the low pressure linkage type pumping device or station inner compressor in well site.In well site work
In skill, associated gas pressurizing is generally carried out using well site low pressure linkage type pumping device as shown in Figure 7, in supercharging point or multi-purpose station
Associated gas pressurizing is generally carried out using station inner compressor at equal websites.
Fig. 8 is that associated gas takes off heavy hydrocarbon cell schematics in the embodiment of the present invention, and it is single to integrate initial separator 10, refrigeration
The skid module that member 6, cold catch pot 16 are integrated.
Fig. 9 is lanthanum chloride hydrate process flow chart in the embodiment of the present invention, and Figure 10 is oil field association in the embodiment of the present invention
Gas hydrate synthesis unit schematic diagram.Integrated liquid storage unit 3, hydration reaction unit 4, defeated processing unit 5 is outside hydrate slurry
The skid module of one.The liquid storage unit 3 is set at 1.2~2m of earth's surface or less；The hydration reaction unit 4 installs height
Degree is 3~7m；5 mounting height of defeated processing unit is 3~7m outside the hydrate slurry, and the water in liquid storage unit 3 is through water delivery
Pump enters hydration reaction unit 4, and the hydrate slurry of generation enters defeated processing unit 5 outside hydrate slurry by gravity flow mode.
The above is the preferred embodiment of the present invention, it is noted that for those skilled in the art
For, various improvements and modifications may be made without departing from the principle of the present invention, these improvements and modifications are also considered as
Protection scope of the present invention.
Claims (9)
1. a kind of oil field accompanying gas recovering device, it is characterised in that：Including de- heavy hydrocarbon unit (1), compress cell (2), liquid storage list
Defeated processing unit (5), refrigeration unit (6), first flowmeter (7), number outside first (3), hydration reaction unit (4), hydrate slurry
According to monitoring unit (8)；
The de- heavy hydrocarbon unit (1) includes associated gas air inlet pipe (9), initial separator (10), the first oil exit pipe (11), first
Exhaust pipe (12), heat exchanger (13), refrigerant pipe (14), second exhaust pipe (15), cold catch pot (16), the second oil exit pipe
(17), third exhaust pipe (18)；
The compress cell (2) includes filter (19), supercharging device (20), second flowmeter (21), the 4th exhaust pipe
(22)；
The initial separator (10) is connect with associated gas air inlet pipe (9), the first oil exit pipe (11), downtake pipe (12),
The heat exchanger (13) is connect with downtake pipe (12), second exhaust pipe (15), passes through refrigerant pipe (14) and refrigeration unit
(6) it connects, the cold catch pot (16) connects with second exhaust pipe (15), the second oil exit pipe (17), third exhaust pipe (18)
It connects, the third exhaust pipe (18) is vented with filter (19), supercharging device (20), second flowmeter (21), the 4th successively
Manage (22) connection, the hydration reaction unit (4) and defeated processing unit (5), system outside the 4th exhaust pipe (22), hydrate slurry
Cold unit (6) connection, is connect by first flowmeter (7) with liquid storage unit (3), the data monitoring unit (8) is to hydration
Defeated processing unit (5), refrigeration unit (6), first flowmeter (7), second flowmeter outside reaction member (4), hydrate slurry
(21) it is monitored.
2. oil field accompanying gas recovering device according to claim 1, it is characterised in that：Cold catch pot (16) packet
Include the first air inlet (34), S types baffle plate (35), the second air inlet (36), collecter ring (37), the first disengagement chamber (38), second
Disengagement chamber (39), third disengagement chamber (40), separation exhaust outlet (41), drain pipe (42), the first separation steering ring (43), first
Gas outlet (44), the first liquid outlet (45), second separation steering ring (46), second exhaust port (47), the second liquid outlet (48),
Third detaches steering ring (49)；
The cold catch pot (16) is divided into upper and lower two chambers, and the lower chambers are equipped with the first air inlet (34), S types
Baffle plate (35), the second air inlet (36), second air inlet (36) are equipped with collecter ring (37), and the upper chamber includes
First disengagement chamber (38), the second disengagement chamber (39), third disengagement chamber (40), first disengagement chamber (38) are equipped with the first separation
Steering ring (43), the first gas outlet (44), the first liquid outlet (45), second disengagement chamber (39) are equipped with the second separation and lead
To loop (46), second exhaust port (47), the second liquid outlet (48), the third disengagement chamber (40) is equipped with third separation and is oriented to
Loop (49), separation exhaust outlet (41), drain pipe (42).
3. oil field accompanying gas recovering device according to claim 1, it is characterised in that：The supercharging device (20) can be adopted
With well site low pressure linkage type pumping device, inner compressor of standing.
4. oil field accompanying gas recovering device according to claim 1, it is characterised in that：The liquid storage unit (3) is set to
Below earth's surface at 1.2~2m.
5. oil field accompanying gas recovering device according to claim 1, it is characterised in that：The hydration reaction unit (4)
Mounting height is 3~7m.
6. oil field accompanying gas recovering device according to claim 1, it is characterised in that：Defeated place outside the hydrate slurry
Reason unit (5) mounting height is 3~7m.
7. oil field accompanying gas recovering device according to claim 1, it is characterised in that：The refrigeration unit (6) includes
First refrigeration system (23), the second refrigeration system (24), compressor (25), cooler (26), surge tank (27)；
The compressor (25), cooler (26), surge tank (27) are sequentially connected, and the surge tank (27) is respectively with first
Refrigeration system (23), the second refrigeration system (24) connection, first refrigeration system (23) include flow control valve (28), the
One throttle valve (29), the second surge tank (30), air bleeding valve (31), tapping valve (32), the flow control valve (28), first segment
Stream valve (29), heat exchanger (13), the second surge tank (30) are sequentially connected, second surge tank (30) and air bleeding valve (31),
Tapping valve (32) connects, and second refrigeration system (24) includes second throttle (33), the second throttle (33)
It is connect with hydration reaction unit (4).
8. a kind of associated gas recovery method, it is characterised in that：Include the following steps；
S1, associated gas remove heavy hydrocarbon
Associated gas enters initial separator (10) through associated gas air inlet pipe (9) and carries out just separation, and the impurity of separation is through first
Oil exit pipe (11) is discharged, and gas phase enters cold catch pot through downtake pipe (12), heat exchanger (13), second exhaust pipe (15)
(16) heavy hydrocarbon removing is carried out；
S2, associated gas pressurizing
It removes the associated gas after heavy hydrocarbon and enters supercharging device (20) progress after filter (19) filtering through third exhaust pipe (18)
Supercharging enters hydration reaction unit (4) after second flowmeter (21) metering through the 4th exhaust pipe (22)；
S3, associated gas synthesized hydrate slurry
The cold fluid that second throttle (33) comes out enters hydration reactor interlayer and provides cold, fluid reservoir (3) for hydration reaction
Interior water enters hydration reaction unit (4), carries out hydration reaction with associated gas after supercharged, data monitoring unit (8), which is collected, to be come
Defeated processing unit (5), refrigeration from outside first flowmeter (7), second flowmeter (21), hydration reaction unit (4), hydrate slurry
The related datas such as temperature, pressure, the flow of unit (6) generate control method using hydrate and carry out production run state modulator；
S4, hydrate slurry working process
Hydrate slurry enters defeated processing unit (5) outside hydrate slurry from hydration reactor (4) and is carried out dehydrating, and removing is big
The slurry of part water enters outer defeated system.
9. associated gas recovery method according to claim 8, it is characterised in that：Hydrate life described in step S3
Include the following steps at control method；
K1, hydrate thermodynamical model is established, carries out Investigation On The Hydrate Formation Conditions prediction
K11, selection predicts that the state equation of Investigation On The Hydrate Formation Conditions, input gas component complete fluid packet in PVTsim softwares
It establishes；
K12, selection Investigation On The Hydrate Formation Conditions prediction module, predict the formation temperature condition of hydrate under different pressures, and export
Fluid packet；
K13, change gas component, complete the Investigation On The Hydrate Formation Conditions prediction of gas with various component, and complete the export of fluid packet；
K2, hydrate kinetic model is established, carries out hydrate nucleation, growth simulation, predicted the generating rate of hydrate, generate
Amount and hydrate slurry fluid viscosity
K21, similar pipeline model is established using OLGA softwares according to the specific structure size of hydrate synthesizing device, and added
Hydrate generates prediction module；
K22, the fluid packet that PVTsim softwares are established, the pressure of input hydrate generation, temperature curve are imported in OLGA softwares
Data；
K23, the inlet flow rate and temperature that gas-liquid is defined in pipeline starting point, pipeline terminal define the operation pressure of hydrate synthesizing device
Power, simulate 1h, 2h ..., in Nh in hydrate synthesizing device hydrate generating rate, production quantity and hydrate slurry
Viscosity change situation；
K24, change liquid-gas ratio, hydrate generating rate, production quantity and hydrate slurry viscosity change situation in simulator；
K25, gas-liquid flow, temperature, the pipeline terminal pressure for changing pipeline starting point respectively, repeat step K23, K24, and simulation is different
The situation of change of the generating rate of hydrate in hydrate synthesizing device under operating mode, production quantity and hydrate slurry fluid viscosity；
K26, the gas flow by under different operating modes, fluid flow, pressure, temperature and reaction time deposit input layer are corresponding
Tables of data, generating rate, production quantity and the corresponding number of hydrate slurry fluid viscosity deposit output layer of corresponding hydrate
According to table；
Fluid packet in K27, change OLGA softwares inputs the corresponding hydrate of the fluid packet and generates pressure, temperature curve data,
Simulate hydrate generating rate under different component of natural gas, production quantity and hydrate slurry fluid viscosity situation of change；
K28, step K23, K24, K25 are repeated, completes different component of natural gas and is hydrated in hydrate synthesizing device under different operating modes
The situation of change simulation of the generating rate, production quantity and hydrate slurry fluid viscosity of object, while repeating step K26 and completing data system
Meter；
K3, establish BP neural network, formed hydrate generating rate, production quantity and hydrate slurry fluid viscosity predictor formula
K31, a feedforward BP neural network with hidden layer is established using MATLAB artificial neural networks tool box, including defeated
Enter layer, middle layer, output layer 3-tier architecture, wherein input layer includes gas flow, fluid flow, hydration reaction pressure, temperature
And 5 neurons of reaction time, output layer include 3 hydrate generating rate, production quantity and hydrate slurry fluid viscosity god
Through member；
K32, input layer data corresponding with output layer are directed respectively into, select suitable excitation function, complete artificial neural network
Training, hydrate generating rate, hydrate production quantity and hydrate slurry are converted to by weights, threshold values and excitation function
The predictor formula of fluid viscosity；
K33, step K32 is repeated, generating speed, production quantity and hydrate slurry fluid viscosity to the hydrate of gas with various component carries out
Training, study, obtain the hydrate generating rate of gas with various component, the predictor formula of production quantity and hydrate slurry fluid viscosity；
K4, by calculating above, in conjunction with hydrate monitoring management system, carry out lanthanum chloride hydrate technology controlling and process management
K41 input natural gas gas component, hydrate generating rate minimum allowable value, hydrate on hydration reaction monitoring panel
Slurry viscosity maximum permissible value, maximum allowble pressure, minimum permissible temperature, hydration reaction monitoring system recall component of natural gas the most
Close hydration reaction predictor formula, when calculating the difference under different gas flow, fluid flow, reaction temperature, reaction pressure
Generating rate, hydrate production quantity and the hydrate slurry fluid viscosity of interior hydrate；
Hydrate generates speed in the data selection prediction result that K42, hydration reaction monitoring system are measured according to natural gas flowmeter
The maximum data of rate are manufacturing parameter, control the liquid inlet volume, pressure and temperature of hydrate synthesizing device；
K43, the pressure according to hydrate synthesizing device, temperature variations, hydration reaction monitoring system real-time display hydrate
Generating rate, production quantity and hydrate slurry fluid viscosity, and choose optimized parameter tune according to hydrate generating rate maximum principle
Save the manufacturing parameter of hydrate synthesizing device；
K44, the time that hydrate tinning is carried out according to amount of capacity, the hydrate production quantity of prediction of hydrate transfer cask are controlled
System.
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| CN112825157A (en) * | 2019-11-20 | 2021-05-21 | 天津大学 | Gasification gas production prediction method, device, equipment and storage medium |
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