阅读说明：本技术 一种天然气模块化试采装置 (Natural gas modularization pilot production device ) 是由 李进 罗军 葛豪飞 于 2021-08-26 设计创作，主要内容包括：本发明公开了一种天然气模块化试采装置,包括辅助区域、露点控制装置、凝析油稳定装置及装车系统,所述露点控制装置主要包括段塞流捕集器、生产分离器、低温分离器、一级闪蒸分离器、二级闪蒸分离器、气气换热器及外输气/凝析油换热器,所述凝析油稳定装置主要包括凝析油稳定塔、凝析油稳定塔重沸器、稳定气空冷器、塔顶气分离器、凝析油换热器。本模块化试采装置具有易于搬迁,安装施工周期短,一套装置多井、多区域试采,以及可处理生产管输天然气等特点；满足探井、边缘区块天然气试采和快速建产的需求,为地面配套建设提供科学合理、真实的单井采集数据；并可快速部署,缓解天然气供需矛盾。(The invention discloses a natural gas modularized pilot production device which comprises an auxiliary area, a dew point control device, a condensate stabilizing device and a loading system, wherein the dew point control device mainly comprises a slug flow catcher, a production separator, a low-temperature separator, a primary flash separator, a secondary flash separator, a gas-gas heat exchanger and an external gas/condensate heat exchanger, and the condensate stabilizing device mainly comprises a condensate stabilizing tower, a condensate stabilizing tower reboiler, a stable gas-air cooler, a tower top gas separator and a condensate heat exchanger. The modularized pilot production device has the characteristics of easy removal, short installation and construction period, multi-well and multi-zone pilot production of one set of device, capability of treating production pipe natural gas and the like; the requirements of natural gas pilot production and rapid production construction of exploratory wells and edge blocks are met, and scientific, reasonable and real single-well acquisition data are provided for ground supporting construction; and can be deployed rapidly, and the contradiction between supply and demand of natural gas is relieved.)

1. The utility model provides a natural gas modularization pilot production device, includes auxiliary area, dew point control device, condensate oil stabilising arrangement and loading system, its characterized in that:

the dew point control device mainly comprises a slug flow catcher, a production separator, a low-temperature separator, a primary flash separator, a secondary flash separator, a gas-gas heat exchanger and an external gas transmission/condensate oil heat exchanger.

2. The condensate oil stabilizing device mainly comprises a condensate oil stabilizing tower, a condensate oil stabilizing tower reboiler, a stable air-air cooler, a tower top gas separator and a condensate oil heat exchanger.

3. The modular natural gas pilot plant of claim 1, wherein: the auxiliary area mainly comprises an instrument air system, a torch system, a rich gas pressurizing sledge, an ethylene glycol regenerating sledge, a closed discharge tank and an open discharge tank.

4. The modular natural gas pilot plant of claim 1, wherein: the loading system mainly comprises a condensate oil storage and loading pump and a quantitative loading crane pipe skid.

5. The modular natural gas pilot plant of claim 1, wherein: the gas coming from the well head is throttled by a first-stage throttle valve and then enters a slug flow catcher for gas-liquid separation, the separated gas phase enters a production separator for secondary gas-liquid separation, the gas phase at the top of the production separator is subjected to alcohol injection and then is subjected to heat exchange and cooling with the gas phase of a low-temperature separator in a gas-gas heat exchanger, then is throttled by a second-stage throttle valve and then is merged with the gas phase separated by a first-stage flash separator and the rich gas pressurized by a rich gas pressurizing sledge and then enters a low-temperature separator for gas-liquid separation, the gas phase of the low-temperature separator is subjected to heat exchange by the gas-gas heat exchanger and then enters an external gas/condensate oil heat exchanger for heat exchange with stable condensate oil, and the natural gas after heat exchange enters an external gas pipeline.

6. The modular natural gas pilot plant of claim 1, wherein: liquid phase separated from the production separator and liquid phase separated from the slug flow catcher are converged and enter the first-stage flash separator for flash evaporation, water phase is discharged to the closed discharge tank, oil phase is converged and enter the second-stage flash tank for secondary flash evaporation, separated alcohol phase is sent to the ethylene glycol regeneration sledge for regeneration, the oil phase separated by the secondary flash tank enters the condensate heat exchanger to exchange heat with the stable condensate at the bottom of the condensate stabilizing tower to recover energy, and then the condensate enters the condensate stabilizing tower, and is in countercurrent contact with a gas phase returned to the stabilizing tower from the top of a reboiler of the condensate stabilizing tower to perform mass and heat transfer, and the stable condensate at the tower bottom is subjected to heat exchange and cooling with an oil phase and an export gas separated from the secondary flash tank through the condensate heat exchanger and the export gas/condensate heat exchanger respectively.

7. The modular natural gas pilot plant of claim 1, wherein: and the gas phase at the top of the condensate oil stabilizing tower is cooled by the stabilizing gas air cooler, then is converged with the gas phase separated by the secondary flash separator, then enters a Soxhlet number tower top gas separator for gas-liquid separation, is pressurized by the rich gas pressurizing sledge, and is then sent to the low-temperature separator, and the liquid phase separated by the tower top gas separator is discharged into a closed discharge tank for storage.

8. The modular natural gas pilot plant of claim 1, wherein: the production separator comprises a production separation pry A and a production separation pry B.

Technical Field

The invention relates to the field of natural gas exploitation, in particular to a natural gas modularized pilot production device.

Background

Under the current situation that natural gas exploration is rapidly developed and a gas field evaluation deployment task is heavy, in order to meet the requirements of natural gas rolling exploration evaluation deployment and gas testing, a set of movable modular natural gas pilot production device with complete functions and reusability needs to be built.

Therefore, a natural gas modular pilot production device is provided to solve the problems.

Disclosure of Invention

The invention aims to provide a natural gas modular trial production device to solve the problems in the background technology.

In order to achieve the purpose, the invention provides the following technical scheme:

a modularized natural gas pilot production device comprises an auxiliary area, a dew point control device, a condensate stabilizing device and a loading system,

the dew point control device mainly comprises a slug flow catcher, a production separator, a low-temperature separator, a primary flash separator, a secondary flash separator, a gas-gas heat exchanger and an external gas transmission/condensate oil heat exchanger.

The condensate oil stabilizing device mainly comprises a condensate oil stabilizing tower, a condensate oil stabilizing tower reboiler, a stable air-air cooler, a tower top gas separator and a condensate oil heat exchanger.

In a further embodiment, the auxiliary area consists essentially of an instrument wind system, a flare system, a rich gas pressurization skid, a glycol regeneration skid, a closed discharge tank, and an open discharge tank.

In a further embodiment, the loading system mainly comprises a condensate oil storage, a loading pump and a quantitative loading crane pipe skid.

In a further embodiment, the well head gas is throttled by a primary throttle valve and then enters the slug flow catcher for gas-liquid separation, the separated gas phase enters the production separator for secondary gas-liquid separation, the gas phase at the top of the production separator is subjected to alcohol injection and then is subjected to heat exchange and cooling with the gas phase of the cryogenic separator in the gas-gas heat exchanger, then is throttled by a secondary throttle valve and then is merged with the gas phase separated by the primary flash separator and the rich gas pressurized by the rich gas pressurizing sledge and then enters the cryogenic separator for gas-liquid separation, the gas phase of the cryogenic separator enters the external gas/condensate heat exchanger for heat exchange with the stable condensate oil after being subjected to heat exchange by the gas-gas heat exchanger, and the natural gas after heat exchange enters an external gas transmission pipeline.

In a further embodiment, the liquid phase separated from the production separator and the liquid phase separated from the slug flow catcher are merged and enter the first-stage flash separator for flash evaporation, the water phase is discharged to the closed discharge tank, the oil phase and the oil phase separated from the low-temperature separator are merged and enter the second-stage flash tank for secondary flash evaporation, the separated alcohol phase is sent to the ethylene glycol regeneration sledge for regeneration, the oil phase separated by the secondary flash tank enters the condensate heat exchanger to exchange heat with the stable condensate at the bottom of the condensate stabilizing tower to recover energy, and then the condensate enters the condensate stabilizing tower, and is in countercurrent contact with a gas phase returned to the stabilizing tower from the top of a reboiler of the condensate stabilizing tower to perform mass and heat transfer, and the stable condensate at the tower bottom is subjected to heat exchange and cooling with an oil phase and an export gas separated from the secondary flash tank through the condensate heat exchanger and the export gas/condensate heat exchanger respectively.

In a further embodiment, the gas phase at the top of the condensate oil stabilizing tower is cooled by the stabilizing gas air cooler, then is merged with the gas phase separated by the secondary flash separator, then enters a Soxhlet number tower top gas separator for gas-liquid separation, the gas phase is pressurized by the rich gas pressurizing sledge, then is sent to the low-temperature separator, and the liquid phase separated by the tower top gas separator is discharged into a closed discharge tank for storage.

In a further embodiment, this is as follows.

Compared with the prior art, the invention has the beneficial effects that:

the modularized pilot production device has the characteristics of easy removal, short installation and construction period, multi-well and multi-zone pilot production of one set of device, capability of treating production pipe natural gas and the like; the requirements of natural gas pilot production and rapid production construction of exploratory wells and edge blocks are met, and scientific, reasonable and real single-well acquisition data are provided for ground supporting construction; and can be deployed rapidly, and the contradiction between supply and demand of natural gas is relieved.

Drawings

Fig. 1 is a schematic structural diagram of a leak source control device of a modular pilot production device.

Fig. 2 is a schematic structural view of a condensate stabilizing device of the modular pilot production device.

Fig. 3 is a schematic view of the leakage point control device, the condensate oil stabilizing device and the instrument automatic control flow in the modular pilot production device.

Fig. 4 is an enlarged schematic structural view of the area a in fig. 3.

Fig. 5 is an enlarged structural diagram of a region B in fig. 3.

Fig. 6 is an enlarged schematic structural view of the region C in fig. 3.

Fig. 7 is a simplified process flow diagram in a modular pilot plant.

Detailed Description

The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.

Referring to fig. 1-7, the present invention provides a natural gas modular pilot production device, which comprises an auxiliary area, a dew point control device, a condensate stabilization device and a loading system, the dew point control device mainly comprises a slug flow catcher, a production separator, a low-temperature separator, a primary flash separator, a secondary flash separator, a gas-gas heat exchanger and an external gas transmission/condensate oil heat exchanger, the condensate stabilizing device mainly comprises a condensate stabilizing tower, a condensate stabilizing tower reboiler, a stable gas air cooler, a tower top gas separator and a condensate heat exchanger, an auxiliary area mainly comprises an instrument air system, a torch system, a rich gas pressurizing sledge, an ethylene glycol regenerating sledge, a closed discharge tank and an open discharge tank, a loading system mainly comprises a condensate storage and loading pump and a quantitative loading crane pipe sledge, and a production separator comprises a production separation sledge A and a production separation sledge B.

Example 1

Referring to fig. 1-7, in the embodiment of the invention, well head incoming gas (10.5-11.6 MPag, 29-32 ℃) is throttled to 8.5MPag by a primary throttle valve and then enters a slug flow catcher V-0101 for gas-liquid separation, separated gas phase enters a production separator V-0102 for secondary gas-liquid separation, gas phase at the top of the production separator is subjected to alcohol injection, then exchanges heat with gas phase of a low-temperature separator V-0103 in a gas-gas heat exchanger E-0101 and is cooled to 0 ℃, then is throttled to 6.04MPag by a secondary throttle valve, and is converged with gas phase separated by a primary flash separator and rich gas boosted to 6.2MPag by a rich gas boosting sledge SK-0103 and then enters a low-temperature separator for gas-liquid separation. The gas phase of the low-temperature separator enters an external gas transmission/condensate heat exchanger E-0105 to exchange heat with stable condensate oil after being subjected to heat exchange by a gas-gas heat exchanger, the natural gas (6.0MPag, 21 ℃) after heat exchange enters an external gas transmission pipeline, the gas coming from a well head enters a natural gas modular pilot production device, the natural gas modular pilot production device is subjected to two-stage throttling and depressurization by a J-T valve, and the dew point of the natural gas is controlled below minus 5 ℃ in a dew point control device by two-stage alcohol injection; the condensate oil generated in the process is stabilized by a condensate oil stabilizing device and then is conveyed into a condensate oil storage tank for storage, and the condensate oil is periodically pulled and loaded, and the process flow diagram is shown in an attached figure 7.

Example 2

Referring to fig. 1-7, based on embodiment 1: liquid phase separated from the production separator is converged with liquid phase separated from the slug flow catcher and then enters a first-stage flash separator V-0104 for flash evaporation, water phase is discharged to a closed discharge tank D-0101, oil phase is converged with oil phase separated from a low-temperature separator V-0103 and then enters a second-stage flash tank V-0105 for secondary flash evaporation, and separated alcohol phase is sent to an ethylene glycol regeneration sledge for regeneration. The oil phase separated from the secondary flash tank enters a condensate heat exchanger E-0103 to exchange heat with stable condensate (0.5MPag, 185 ℃) at the bottom of a stabilizing tower to recover energy, and then enters a stabilizing tower C-0101 to perform countercurrent contact with the gas phase returned to the stabilizing tower from the top of a condensate stabilizing tower reboiler E-0102 (an electric heater) to perform mass and heat transfer. And (3) the stable condensate oil at the tower bottom is subjected to heat exchange and cooling with the oil phase and the gas output separated from the secondary flash tank respectively through a condensate oil heat exchanger E-0103 and an output gas/condensate oil heat exchanger E-0105, and then is conveyed to a condensate oil storage tank for storage. Cooling the gas phase at the top of the condensate oil stabilizing tower by a stabilizing gas air cooler A-0103, then converging the gas phase separated by the secondary flash separator, then entering a tower top gas separator V-0107 for gas-liquid separation, boosting the gas phase to 6.2MPag by a rich gas boosting sledge, and then sending the gas phase to a low-temperature separator; and discharging the liquid phase separated by the gas separator at the top of the tower into a closed discharge tank for storage.

It is worth to say that

The product of the natural gas modularized pilot production device is divided into commodity natural gas and stable condensate oil, and the specific design indexes are as follows:

1) the pressure of the commercial natural gas discharged from the device is 5.8-6.0 MPag;

2) the commodity natural gas meets the requirements of natural gas GB 17820 and 2018, and the dew point of hydrocarbon and water is less than or equal to-5 ℃;

3) the stable condensate oil meets the requirements of 'condensate gas field ground engineering design Specification' SY/T0605-2016, and the saturated vapor pressure is less than or equal to 0.7 times of local atmospheric pressure at 37.8 ℃.

Main equipment list and bit number

Description of the control System of the present apparatus

DCS interlocking turn-off system

Description of shutdown level

The natural gas modularized pilot production device is not provided with an ESD system, and an instrument control system is a DCS. A secondary shutdown signal is set in the DCS system, and the description of the secondary shutdown signal is as follows:

(1) first order shutdown (USD-01)

And (5) emergency shutdown of the whole plant. And all production devices of the whole gas field are closed by a manual turn-off button arranged in the instrument control room or a turn-off triggered by the pressure exceeding the station entrance and exit, and an emptying valve is opened.

(2) Second order Shutdown (SD)

The cell or equipment is turned off. The single body or equipment process detection parameter is out of limit, so that the operation of the device is not influenced when the device is stopped within a certain time, and the instrument control room receives the process parameter out-of-limit alarm signal and carries out field processing by operators.

Description of shutdown

(1) USD-01 shutoff signal

And a manual turn-off button or an ultra-high inbound pressure (PIT-0101A/B, alternative) and outbound pressure (PIT-0307A/B, alternative) arranged in the instrument control room → USD-01 → all production devices of the whole gas field are turned off, and an emergency emptying valve is opened. Namely, turning off: SDV-0104, SDV-0102, SDV-0201, SDV-0301, SDV-0302, SDV-0401, SDV-0501, SDV-1101, SDV-0701, SDV-1301, SDV-0103, a two-stage flash separator electric heater EH-0101, a condensate stabilizer reboiler E-0102, a sewage pump P-0101, a sump oil pump P-0104A/B, a condensate loading pump P-0105A/B, a stable gas air cooler A-0103, a rich gas pressurizing sledge SK-0103 (controlled by a PLC system of the rich gas pressurizing sledge), an ethylene glycol regenerating sledge SK-1501 (controlled by the PLC system of the ethylene glycol regenerating sledge), and BDV-0101 and BDV-0303 are opened.

And a manual turn-off button or low alarm of station entering pressure (PIT-0101A/B, alternative) and station leaving pressure (PIT-0307A/B, alternative) arranged in the instrument control room → USD-01 → all production devices of the whole gas field are turned off, and the devices are not emptied. Namely, turning off: SDV-0104, SDV-0102, SDV-0201, SDV-0301, SDV-0302, SDV-0401, SDV-0501, SDV-1101, SDV-0701, SDV-1301, SDV-0103, a two-stage flash separator electric heater EH-0101, a condensate stabilizer reboiler E-0102, a sewage pump P-0101, a sump oil pump P-0104A/B, a condensate loading pump P-0105A/B, a stable gas air cooler A-0103, a rich gas pressurizing sledge SK-0103 (controlled by a PLC system of the rich gas pressurizing sledge), and an ethylene glycol regenerating sledge SK-1501 (controlled by the PLC system of the ethylene glycol regenerating sledge).

(2) SD off signal

The slug flow catcher V-0101 liquid level transmitter LIT-0102 low liquid level signal → liquid level low shut-off signal SD-01 → shut-off SDV-0102.

The production separator V-0102 liquid level transmitter LIT-0202 liquid level low signal → liquid level low shutdown signal SD-02 → shutdown SDV-0201.

The low temperature separator V-0103 liquid level transducer LIT-0402 liquid level low signal → liquid level low turn-off signal SD-03 → turn-off SDV-0401.

And the loading system operates a column manual pump stopping signal on site → a condensate oil loading pump P-0104A/B pump stopping signal SD-04 → P-0104A/B is turned off.

Stabilizing the vibration sensor VT-0702 of the air cooler A-0103 to vibrate the high signal → vibrate the high turn-off signal SD-05 → turn-off A-0103.

The loading system operates the column on site to manually stop the loading system signal → the condensate loading system shut-off signal SD-06 → shut-off P-0104A/B, SDV-0302 and SDV-1101.

The primary flash separator V-0104 pressure transmitter PIT-0503 pressure high signal → pressure high shutoff signal SD-07 → shutoff SDV-0102 and SDV-0201.

The primary flash separator V-0104 liquid level transmitter LIT-0503 liquid level low signal → liquid level low shut-off signal SD-08 → shut-off SDV-0501.

The pressure high signal → the pressure high shutoff signal SD-09 → the shutoff SDV-0401 and the SDV-0501 of the pressure transmitter PIT-0601 of the two-stage flash separator V-0105.

Description of DCS control

(1)PIT-0101A/B→PIRA-0101A/B

Pressure detection, display, accumulation, interlocking and alarm (high pressure alarm value: 12.0 MPag; low alarm value: 10.0MPag) at the well head gas inlet.

(2) Pressure control loop PIT-0102 → PIRCA-0102 → PV-0101

The gas inlet pressure of the front well mouth of the primary throttle valve and the opening of the primary throttle valve PV-0101 form a control loop, and when the detected pressure is higher than the normal set value by 10.5MPag, the opening of the valve PV-0101 is increased; and when the detected pressure is lower than the set value of 10.5MPag, reducing the opening degree of the valve PV-0101. When the detection pressure reaches 11.8MPag, alarming high; when the pressure reaches 10.2MPag, then the alarm is low.

(1)PIT-0104→PIRA-0104

The pressure of the gas phase outlet of the slug flow catcher V-0101 is detected, displayed, accumulated and alarmed (the high alarm value of the pressure is 9.0MPag, the low alarm value is 8.0 MPag).

(2)TIT-0104→TIRA-0104

The temperature of the gas phase outlet of the slug flow catcher V-0101 is detected, displayed, accumulated and alarmed (the temperature is high alarm value: 35 ℃ and the low alarm value: 25 ℃).

(3) Liquid level control loop LIT-0101 → LICCA-0101 → LV-0101

The liquid level of the slug flow catcher V-0101 and the opening of the liquid level control valve LV-0101 form a control loop, and when the detected liquid level is 500mm higher than the normal set value, the opening of the valve LV-0101 is increased; and when the detected liquid level is 500mm lower than the normal set value, reducing the opening degree of the valve LV-0101. When the detected liquid level reaches 650mm, alarming is performed; when the liquid level reaches 350mm, the alarm is low.

(4) Liquid level control loop LIT-0102 → LIRCSA-0102 → SDV-0103

The liquid level of the slug flow catcher V-0101, the switch valves SDV-0103 and SDV-0102 form an interlocking control loop, when the detected liquid level reaches 1800mm, the high alarm is given, the SDV-0103 is started, and when the liquid level reaches 250mm, the low alarm is given, and the SDV-0102 is interlocked and turned off.

(1)PIT-0201→PIRA-0201

The production separator V-0102 gas phase pressure is detected, displayed, accumulated and alarmed (high pressure alarm value: 9.0 MPag; low alarm value: 8.0 MPag).

(2) Liquid level control loop LIT-0201 → LICCA-0201 → LV-0201

The liquid level of the production separator V-0102 and the opening of the liquid level control valve LV-0201 form a control loop, and when the detected liquid level is 450mm higher than a normal set value, the opening of the valve LV-0201 is increased; and when the detected liquid level is 450mm lower than the normal set value, reducing the opening degree of LV-0201. When the detected liquid level reaches 550mm, alarming at high; when the liquid level reaches 350mm, the alarm is low.

(3) Liquid level control loop LIT-0202 → LIRSA-0202 → SDV-0201

The liquid level of the production separator V-0102 and the switch valve SDV-0201 form an interlocking control loop, and when the detected liquid level reaches 550mm, a high alarm is given; when the liquid level reaches 250mm, a low alarm is given, and the SDV-0201 is switched off in an interlocking mode.

(1)PIT-0301→PIRA-0301

The pressure of the ethylene glycol injection pipeline is detected, displayed, accumulated and alarmed (the alarm value of low pressure is 12.0 MPag).

(2)TIT-0301→TIRA-0301

The pressure of the ethylene glycol injection pipeline is detected, displayed, accumulated and alarmed (the temperature is high alarm value: 35 ℃ C.; the low alarm value: 25 ℃ C.).

(3)PDIT-0302→PDIRA-0302

Detecting, displaying, accumulating and alarming the E-0101 tube side pressure difference of the gas-gas heat exchanger (the high alarm value of the pressure difference is 20 kPa).

(4) Temperature control loop TIT-0306 → TIRCA-0306 → TV-0302

And the tube pass outlet temperature of the gas-gas heat exchanger E-0101 and the opening degree of the temperature control valve TV-0302 form a control loop, and when the detected tube pass outlet temperature is higher than the normal set value by 0 ℃, the opening degree of TV-0302 is reduced. And when the temperature of the outlet of the detection tube pass is higher than 1 ℃, giving an alarm.

(5)TIT-0302→TIRA-0302

The temperature of the shell pass outlet of the gas-gas heat exchanger E-0101 is detected, displayed, accumulated and alarmed (the temperature is high at 25 ℃ and the low at 15 ℃).

(6) Pressure control loop PIT-0302 → PIRCA-0302 → PV-0302

The external gas pressure and the opening degree of the pressure control valve PV-0302 form a control loop, and when the detected external gas pressure is higher than the normal set value of 6.0MPag, the opening degree of the valve PV-0302 is increased; and when the detected external gas output pressure is lower than the normal set value of 6.0MPag, reducing the opening degree of the valve PV-0302. When the detected output air pressure is higher than 6.1, alarming is high; and when the detected external air output pressure is lower than 5.8MPag, alarming is low.

(7)PIT-0307A/B→PIRA-0307A/B

Detecting, displaying, accumulating, interlocking and alarming the pressure of the external air output (the high alarm value of the pressure is 6.2MPag, and the low alarm value is 5.6 MPag).

(1) Pressure control loop PIT-0401 → PIRCA-0401 → PV-0401

The natural gas pressure at the front end of the secondary throttle valve and the opening of the secondary throttle valve PV-0401 form a control loop, and when the detected pressure is higher than the normal set value of 8.48MPag, the opening of the valve PV-0401 is increased. When the detection pressure reaches 9.0MPag, a high alarm is given.

(2)TIT-0402→TIRA-0402

The temperature of the second-stage throttling natural gas is detected, displayed, accumulated and alarmed (the temperature is high, the alarm value is minus 8 ℃, and the alarm value is low, the temperature is minus 16 ℃).

(3)PIT-0403→PIRA-0403

Pressure detection, display, accumulation and alarm of the low-temperature separator (high pressure alarm value: 6.2MPag and low alarm value: 5.8 MPag).

(4)TIT-0405→TIRA-0405

The temperature of the gas phase outlet of the low-temperature separator is detected, displayed, accumulated and alarmed (the temperature is lower than an alarm value of minus 16 ℃).

(5) Liquid level control loop LIT-0401 → LICCA-0401 → LV-0401

The liquid level of the low-temperature separator V-0103 and the opening degree of a liquid level control valve LV-0401 form a control loop, and when the detected liquid level is 500mm higher than a normal set value, the opening degree of the valve LV-0401 is increased; and when the detected liquid level is 500mm lower than the normal set value, reducing the opening degree of the valve LV-0401. When the detected liquid level reaches 600mm, alarming; when the liquid level reaches 400mm, the alarm is low.

(6) Liquid level control loop LIT-0402 → LIRSA-0402 → SDV-0401

The liquid level of the low-temperature separator V-0103 and the switch valve SDV-0401 form an interlocking control loop, and when the detected liquid level reaches 600mm, a high alarm is given; when the liquid level reaches 300mm, low alarm is given, and the SDV-0401 is interlocked and turned off.

(7)PIT-0405→PIRA-0405

The pressure of the ethylene glycol injection pipeline is detected, displayed, accumulated and alarmed (the alarm value of low pressure is 12.0 MPag).

(1) Liquid level control loop LIT-0501 → LICCA-0501 → LV-0501

The oil phase liquid level of the first-stage flash separator V-0104 and the opening degree of a liquid level control valve LV-0501 form a control loop, and when the detected liquid level is 700mm higher than the normal set value, the opening degree of the valve LV-0501 is increased; and when the detected liquid level is 700mm lower than the normal set value, reducing the opening degree of the valve LV-0501. When the detected liquid level reaches 1050mm, alarming at high; when the liquid level reaches 350mm, the alarm is low.

(2) Liquid level control loop LIT-0502 → LICCA-0502 → LV-0502

The liquid level of the water phase of the first-stage flash separator V-0104 and the opening degree of a liquid level control valve LV-0502 form a control loop, and when the detected liquid level is 800mm higher than a normal set value, the opening degree of the valve LV-0502 is increased; and when the detected liquid level is lower than the normal set value by 800mm, reducing the opening degree of the valve LV-0502. When the detected liquid level reaches 1400mm, alarming; when the liquid level reaches 200mm, the alarm is low.

(3) Pressure control loop PIT-0503 → PIRCSA-0503 → PV-0503, SDV-0102, SDV-0201

The gas phase outlet pressure of the first-stage flash separator V-0104 and the opening degree of the pressure control valve PV-0503 form a control loop, and when the detection pressure is higher than the normal set value of 6.14MPag, the opening degree of the valve PV-0503 is increased; when the detected pressure is lower than the normal set value of 6.14MPag, the opening degree of the valve PV-0503 is reduced. When the detection pressure reaches 6.2MPag, alarming high; when the detected pressure reaches 5.8MPag, the alarm is low. When the detection pressure reaches 6.4MPag, a high alarm is given, and the SDV-0102 and the SDV-0201 are interlocked and shut off.

(4) Liquid level control loop LIT-0503 → LIRSA-0503 → SDV-0501

And the liquid level of the oil phase of the first-stage flash separator gas V-0104 and the switch valve SDV-0501 form an interlocking control loop, when the liquid level reaches 250mm, a low alarm is given, and the SDV-0501 is interlocked and turned off.

(1) Liquid level control loop LIT-0601 → LICCA-0601 → LV-0601

The oil phase liquid level of the secondary flash separator V-0105 and the opening degree of the liquid level control valve LV-0601 form a control loop, and when the detected liquid level is 450mm higher than a normal set value, the opening degree of the valve LV-0601 is increased; when the detected liquid level is 450mm lower than the normal set value, the opening degree of the valve LV-0601 is reduced. When the detected liquid level reaches 700mm, alarming at high; when the liquid level reaches 200mm, the alarm is low.

(2) Liquid level control loop LIT-0602 → LICCA-0602 → LV-0602

The alcohol phase liquid level of the secondary flash separator V-0105 and the opening degree of a liquid level control valve LV-0602 form a control loop, and when the detected liquid level is 800mm higher than a normal set value, the opening degree of the valve LV-0602 is increased; when the detected liquid level is 800mm lower than the normal set value, the opening degree of the valve LV-0602 is reduced. When the detected liquid level reaches 1400mm, alarming; when the liquid level reaches 200mm, the alarm is low.

(3) Temperature control loop TIT-0601 → TIRCA-0601 → EH-0101

The liquid phase temperature of the secondary flash separator V-0105 and the electric heater EH-0101 of the secondary flash separator form an interlocking control loop, and when the detected temperature is 20 ℃ higher than the normal set value, the output power of the EH-0101 is reduced; when the detected temperature is 20 ℃ lower than the normal set value, the output power of the EH-0101 is increased. When the detection temperature reaches 40 ℃, alarming is high; when the temperature reaches 18 ℃, the alarm is low.

(4) Pressure control loop PIT-0601 → PIRCSA-0601 → PV-0601, SDV-0401, SDV-0501

The pressure of the secondary flash separator V-0105 and the opening degree of the pressure control valve PV-0601 form a control loop, and when the detected pressure is higher than the normal set value of 0.7MPag, the opening degree of the valve PV-0601 is increased; when the detected pressure is lower than the normal set value of 0.7MPag, the opening degree of the valve PV-0601 is reduced. When the detection pressure reaches 0.8MPag, alarming high; when the detected pressure reaches 0.6MPag, the alarm is low. And when the detected pressure reaches 0.9MPag, high alarm is given, and the SDV-0401 and the SDV-0501 are switched off in an interlocking way.

(1) Liquid level control loop LIT-0701 → LICCA-0701 → LV-0701

The liquid level of the condensate stabilizing tower C-0101 and the opening degree of a liquid level control valve LV-0701 form a control loop, and when the detected liquid level is 1800mm higher than a normal set value, the opening degree of the valve LV-0701 is increased; and when the detected liquid level is 1800mm lower than the normal set value, reducing the opening degree of the valve LV-0701. When the detected liquid level reaches 3300mm, alarming; when the liquid level reaches 300mm, the alarm is low.

(2) Temperature control loop TIT-0704 → TIRCA-0704 → E-0102

The liquid phase temperature of the condensate stabilizing tower C-0101 and a reboiler E-0102 of the condensate stabilizing tower form a control loop, and when the detected temperature is 185 ℃ higher than a normal set value, the output power of the E-0102 is reduced; when the detected temperature is lower than the normal set value of 185 ℃, the output power of E-0102 is increased. When the detection temperature reaches 190 ℃, alarming is high; when the temperature reaches 180 ℃, the alarm is low.

(3)PIT-0702/PIT-0703→PIRA-0702/PIRA-0703

And (4) detecting, displaying, accumulating and alarming the differential pressure of the condensate stabilizing tower (the high alarm value of the differential pressure is 30 kPa).

(4)TIT-0701→TIRA-0701

The temperature of the gas at the top of the condensate stabilizer tower is detected, displayed, accumulated and alarmed (the temperature is high alarm value: 160 ℃ C., and the low alarm value: 145 ℃ C.).

(5) Pressure control loop PIT-0701 → PIRCA-0701 → PV-0701

The top gas pressure of the condensate stabilizer C-0101 and the opening of the pressure control valve PV-0701 form a control loop, and when the detected pressure is higher than the normal set value of 0.47MPag, the opening of the valve PV-0701 is increased; when the detected pressure is lower than the normal set value of 0.47MPag, the opening degree of the valve PV-0701 is reduced. When the detection pressure reaches 0.5MPag, alarming high; when the pressure reaches 0.25MPag, then the alarm is low.

(6) Temperature control loop TIT-0706 → TIRCA-0706 → A-0103

The temperature of the top gas of the tower and the stable air cooler A-0103 form a control loop, and when the detected temperature is 50 ℃ higher than a normal set value, the frequency of the A-0103 motor is increased; and when the detected temperature is 50 ℃ lower than the normal set value, reducing the frequency of the A-0103 motor. When the detection temperature reaches 52 ℃, alarming is high; when the temperature reaches 45 ℃, the alarm is low.

(7) Vibration interlocking control loop VT-0702 → VIA-0702 → A-0103

And the vibration of the stable air cooler A-0103 and the stable air cooler motor form an interlocking control loop, when the detected vibration reaches 4.6mm/s, the high alarm is given, and the stable air cooler motor is switched off in an interlocking manner.

(8) Liquid level control loop LIT-0703 → LIRSA-0703 → SDV-0701

The gas V-0107 liquid level of the gas separator at the tower top and the switch valve SDV-0701 form an interlocking control loop, when the liquid level reaches 600mm, a high alarm is given, and the SDV-0701 is interlocked and opened; when the liquid level reaches 200mm, the alarm is low, and the SDV-0701 is closed in an interlocking mode.

(1)PIT-1203→PIRA-1203

And D-0101 pressure detection, display, accumulation and alarm (high pressure alarm value: 0.05MPag) for the closed-row tank.

(2)LIT-1202→LIRA-1202

And (3) detecting, displaying, accumulating and alarming the liquid level of the closed discharge tank D-0101 (the high alarm value of the liquid level is 2000mm, and the low alarm value is 200 mm).

(3) Liquid level control loop LIT-1201 → LICCA-1201 → P-0101

The liquid level of the discharge tank D-0102 and the sewage pump P-0101 form an interlocking control loop, when the liquid level reaches 1600mm, a high alarm is given, and the sewage pump is interlocked and started; when the liquid level reaches 300mm, alarming is performed low, and the opening of the sewage pump is reduced in an interlocking manner; when the liquid level reaches 200mm, the low alarm is given, and the sewage pump is switched off in an interlocking way.

(1) Liquid level control loop LIT-1301 → LICCA-1301 → SDV-1301

The liquid level of the torch liquid separating tank V-0106 and the switch valve SDV-1301 form an interlocking control loop, when the liquid level reaches 600mm, a high alarm is given, and the SDV-1301 is interlocked and opened; when the liquid level reaches 200mm, a low alarm is given, and the SDV-1301 is switched off in an interlocking manner.

(1) Pressure control loop PIT-1401 → PIRCA-1401 → PV-1401

The pressure of a gas-phase inlet pipeline of the rich gas pressurizing sledge SK-0103 and the opening of a pressure control valve PV-1401 form a control loop, and when the detected pressure is higher than a normal set value of 0.45MPag, the opening of the valve PV-1401 is increased; when the sensed pressure is below the normal set value of 0.45MPag, the opening of the valve PV-1401 is reduced. When the pressure reaches 0.5MPag, alarming high; when the pressure reaches 0.2MPag, the alarm is low.

(1)LIT-1601A～F→LIRA-1601A～F

The condensate storage tank D-0108A-F liquid level detection, display, accumulation and alarm (liquid level high alarm value: 2000 mm; low alarm value: 200 mm).

1. System check of the present device

(1) Before driving, all scaffolds and construction equipment irrelevant to production are checked, confirmed and cleaned, and garbage in a working area is removed. Strictly forbidding irrelevant personnel to enter the operation area;

(2) checking the integrity of the process flow according to P & ID;

(3) after the installation of instruments, instrument valves and the like in the process flow pipeline is checked, single machine debugging records are checked;

(4) checking and confirming DCS and PLC cabinet installation and debugging records;

(5) the installation of running equipment and debugging records are checked, and power can be stably supplied;

(6) testing the intensity test records of the inspection equipment and the pipeline system;

(7) checking and confirming the installation condition of the components in the equipment;

(8) auxiliary systems such as instrument wind, compressed air, nitrogen, electricity and the like meet the driving requirements.

2. Device purging, air tightness test, nitrogen replacement and system drying principle requirement

a) Principle and requirement of purging

(1) When in purging, the device and the machine are used as boundary lines, and the pipelines are purged section by section;

(2) the purging sequence is preferably that the trunk line is first and the branch line is second;

(3) when air is used for blowing, a large compressor or a large air storage tank of the production device is preferably used for blowing intermittently;

(4) the speed of the purge gas flow should be more than 20m/s, and the purge pressure should not be more than the design pressure of the system container and pipeline;

(5) before purging, a blind plate is added in front of the inlet side of equipment such as a heat exchanger, a tower and the like, only the equipment can enter the equipment after the upstream purging is qualified, and under the general condition, the heat exchanger body does not participate in air purging;

(6) when the system is required to control the blowing air volume during blowing, a temporary blowing valve is selected;

(7) during purging, the joint of the safety valve and the pipeline is disconnected, and a blind plate or a baffle is added to prevent dirty impurities from being purged to the bottom of the valve so as to cause the sealing surface of the bottom of the safety valve to be abraded;

(8) in the purging process, only after the upstream system is qualified, the purging air can enter the downstream system through a normal flow;

b) principle and requirement of air tightness test

(1) The gas for the gas tightness test is compressed air, instrument wind or nitrogen, and the gas tightness test cannot be carried out by toxic gas or combustible gas;

(2) in order to prevent the gas on the high-pressure side from leaking to the low-pressure side to cause overpressure on the low-pressure end, a manual valve at a high-low pressure variable stage is closed, and the pressure change condition of the low-pressure side is observed;

(3) during the pressure boosting of the device, if equipment and pipeline deformation, displacement or abnormal metal noise occurs, the pressure boosting is immediately stopped, pressure relief processing is carried out if necessary, and the next operation is determined after reasons are found out;

(4) reporting the pressure drop of the system to a technician in time, and carrying out detailed inspection and analysis to find out the position of a leakage point, and rectifying and eliminating the leakage;

(5) when the leakage of gas is found, a technician is reported in time, the pressure is stopped to be boosted, the pressure is released, then the rectification is carried out, and forced rectification under the pressure is strictly forbidden;

(6) during the airtight test, when the specified test is reached, the pressure rise is suspended, standing observation is carried out for 10-15 minutes, whether the pressure of the pressure test area is stable or not is observed, and leakage detection is carried out on the parts which are possibly leaked, such as a pipeline flange, a static equipment manhole, an instrument connector, a rotating equipment inlet and outlet connected with a pipeline, a valve sealing point and the like in the pressure test area on the premise that the system pressure is stable by using a leakage testing agent. During the inspection, the pressure test medium cannot be continuously injected into the pressure test area. Under the premise of no leakage, the pressure test area can be continuously boosted.

(7) After the pressure relief is finished, the pressure relief point valve is switched off;

(8) a warning fence is arranged at the periphery of the airtight test area, and a warning board is placed on the warning fence.

c) Principle and requirement of Nitrogen replacement

(1) In the whole nitrogen replacement process, an operator must wear the portable oxygen content detector, and the operator stands in the upwind direction to prevent asphyxiation;

(2) warning lines and warning marks must be set at each exhaust point;

(3) the nitrogen replacement time is selected in the daytime, which is beneficial to all the work such as detection and the like;

(4) in the blowing and replacing operation process, each pipeline is blown to be blown through as much as possible, no omission or dead angles exist, and the situation that the blown part is blown away and mixed gas is blown in again is avoided;

(5) the central control cooperates with a regulating valve and a shut-off valve related to the field control replacement process;

(6) according to the flow direction of the device, sequentially opening a blowdown valve and an atmospheric valve of each device for replacement;

(7) during the replacement process, the system is properly kept in a micro-positive pressure state slightly higher than the atmospheric pressure for replacement;

(8) in the process along the displacement line, all the point positions with high and low discharge ports are subjected to exhaust displacement.

3. Key control point for driving device

The matters needing attention in the driving process are as follows:

(1) before the air-tight test of the device, fillers and tower internals are required to be arranged in a condensate stabilizing tower, an ethylene glycol regeneration tower and the like;

(2) when nitrogen is replaced, the oxygen content in each exhaust point is less than or equal to 2 percent (v percent), and the water content in the outlet gas is less than or equal to 50ppm, so that the replacement is qualified;

(3) after the nitrogen replacement is qualified, the system is pressurized to micro positive pressure and then oxygen is isolated;

4. normal driving

4.1 Normal driving stage natural gas modularization trial production device normal driving mainly divide into 2 stages:

(1) introducing raw material gas, and building pressure on the device according to different pressure parts of the device;

(2) the level of the part of the plant is established using a J-T valve (primary and secondary throttling).

4.2 notes on normal driving

In order to ensure the smooth driving of the natural gas modular trial production device, the following requirements are required to be met:

(1) the device is driven according to the general rule of chemical production;

(2) the raw gas should meet the gas composition given in the design basis;

(3) the pressure rise should be slow, and the pressure build-up rate is 0.05 MPa/min;

(4) ensuring that the safety system is put into use;

(5) the oxygen content in the device is less than or equal to 2.0 percent (v percent);

(6) confirming that all valves are in the correct open or closed position before feeding the raw materials;

(7) the load of the device for initial start-up is controlled to be about 50%;

(8) during the pressure building period, a leakage test is carried out and corresponding inspection is carried out, and if serious leakage occurs, the introduction of feed gas is stopped;

(9) the process of driving the vehicle is carried out slowly, so that equipment damage and casualties are firmly avoided;

(10) keeping communication smooth in the driving process, and firmly listening to the unified arrangement of driving commands;

(11) when the automobile is driven, particularly in the process of boosting and heating, field personnel need to continuously inspect the automobile irregularly to prevent equipment and pipelines from leaking;

(12) during driving, the parameter change must be closely noticed to prevent over-temperature and over-pressure.

5. Device parking

5.1 Normal stop

A normal stop is an operation planned in advance for maintenance, repair, or the like. The main purpose of normal parking is to protect the equipment from possible damage and to maintain the equipment in a condition suitable for safe and quick start-up. After receiving the parking instruction, contacting the personnel at the position of the device to prepare for parking.

5.2 Emergency stop

Emergency stop is the emergency stop treatment in the production process if accidents such as sudden power failure (power loss), instrument wind (air loss), equipment failure and the like occur.

It will be evident to those skilled in the art that the invention is not limited to the details of the foregoing illustrative embodiments, and that the present invention may be embodied in other specific forms without departing from the spirit or essential attributes thereof. The present embodiments are therefore to be considered in all respects as illustrative and not restrictive, the scope of the invention being indicated by the appended claims rather than by the foregoing description, and all changes which come within the meaning and range of equivalency of the claims are therefore intended to be embraced therein. Any reference sign in a claim should not be construed as limiting the claim concerned.

Furthermore, it should be understood that although the present description refers to embodiments, not every embodiment may contain only a single embodiment, and such description is for clarity only, and those skilled in the art should integrate the description, and the embodiments may be combined as appropriate to form other embodiments understood by those skilled in the art.