CN107152250B - Method for removing hydrogen sulfide in drilling fluid for drilling operation of sulfur-containing stratum - Google Patents
Method for removing hydrogen sulfide in drilling fluid for drilling operation of sulfur-containing stratum Download PDFInfo
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- CN107152250B CN107152250B CN201710567443.2A CN201710567443A CN107152250B CN 107152250 B CN107152250 B CN 107152250B CN 201710567443 A CN201710567443 A CN 201710567443A CN 107152250 B CN107152250 B CN 107152250B
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- hydrogen sulfide
- separation tank
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/06—Arrangements for treating drilling fluids outside the borehole
- E21B21/063—Arrangements for treating drilling fluids outside the borehole by separating components
- E21B21/067—Separating gases from drilling fluids
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/06—Arrangements for treating drilling fluids outside the borehole
- E21B21/068—Arrangements for treating drilling fluids outside the borehole using chemical treatment
Abstract
The invention discloses a method for removing hydrogen sulfide in drilling fluid for drilling operation of a sulfur-containing stratum, and relates to the technical field of oil drilling closed drilling processes. The invention adopts multiple technical measures of automatic temperature rise, mechanical turbulence, submerged injection and negative pressure extraction and separation, and improves the separation efficiency of hydrogen sulfide in the drilling fluid. The method can separate the hydrogen sulfide gas and the hydrolytic hydrogen sulfide in the drilling fluid in a completely closed environment, can prevent the hydrogen sulfide in the drilling fluid from volatilizing into the air at a conventional solid control system to cause damage to personnel and the environment, and meets the safety requirement of the drilling operation of a sulfur-containing stratum.
Description
Technical Field
The invention relates to the technical field of oil drilling closed drilling processes, in particular to a method for removing hydrogen sulfide in drilling fluid for drilling operation in a sulfur-containing stratum.
Background
The drilling technology is divided into conventional drilling and underbalanced drilling according to the difference between the liquid column pressure of the drilling fluid at the bottom of the well and the formation pressure. Underbalanced drilling is referred to when the bottom hole pressure is less than the formation pressure. During underbalanced drilling, formation fluids may enter the wellbore and return to the surface with drilling fluid. The underbalanced drilling technology has the advantages of improving the drilling efficiency, protecting the reservoir, improving the oil and gas yield and the like. However, when a drilling tool encounters a sulfur-containing stratum, because no corresponding drilling fluid hydrogen sulfide closed treatment equipment is provided, the drilling fluid ground circulating system of the conventional underbalanced drilling process mainly comprises a throttling manifold, a multiphase separator, a solid control system, a circulating tank and other treatment devices. The liquid-gas separator in the circulating system is mainly used for separating formation gas returned from a shaft by well drilling fluid, and the sulfur-containing formation contains natural gas, hydrogen sulfide and other gases. If the multiphase separator cannot completely separate and treat the formation gas in the surface circulating system, the possibility of hydrogen sulfide gas escaping from the drilling fluid discharged to the solid control system is caused, and the harm is caused to operators. Too much hydrogen sulfide gas, if not completely separated, can also cause corrosive damage to equipment and downhole tools in the circulation system.
The invention discloses an invention patent with a publication number of CN101525993A, namely a method for monitoring and controlling hydrogen sulfide in sulfur-bearing stratum underbalanced drilling well in 2009 and 9 days in 2009, wherein the invention patent is characterized in that the content of hydrogen sulfide in drilling fluid is monitored when the drilling fluid passes through a closed sampler, a monitored hydrogen sulfide content signal is input into a control system, the control system converts the monitored hydrogen sulfide content signal into the amount of a required desulfurizing agent and sends an instruction, and the desulfurizing agent is injected into a four-phase separator to react the hydrogen sulfide in the drilling fluid with the desulfurizing agent so as to remove residual hydrogen sulfide.
In the method for treating hydrogen sulfide in the prior art, the excessive addition of the sulfur removal agent into the drilling fluid can affect the performance of the drilling fluid material to a certain extent, so that the addition amount of the sulfur removal agent is limited to a certain extent, and after the addition amount of the sulfur removal agent is limited, the removal effect and efficiency of the hydrogen sulfide can be affected, and the hydrogen sulfide in the drilling fluid can not be removed well.
Disclosure of Invention
In order to overcome the defects and shortcomings in the prior art, the invention provides a method for removing hydrogen sulfide in drilling fluid for drilling operation of a sulfur-containing stratum. The method can separate the hydrogen sulfide gas and the hydrolytic hydrogen sulfide in the drilling fluid in a completely closed environment, can prevent the hydrogen sulfide in the drilling fluid from volatilizing into the air at a conventional solid control system to cause damage to personnel and the environment, and meets the safety requirement of the drilling operation of a sulfur-containing stratum.
In order to solve the defects in the prior art, the invention is realized by the following technical scheme:
the method for removing hydrogen sulfide in the drilling fluid for the drilling operation of the sulfur-containing stratum is characterized by comprising the following steps of: returning the drilling fluid containing hydrogen sulfide out of the well, reducing the pressure of the drilling fluid, then feeding the drilling fluid into a separation tank, centrifugally separating the drilling fluid fed into the separation tank, separating gas obtained after centrifugal separation from the upper part of the separation tank, and enabling the separated drilling fluid to fall into the separation tank; heating and adjusting the drilling fluid through a drilling fluid heating system; stirring and disturbing fluid at the bottom of the drilling fluid in the separation tank; pumping the drilling fluid at the drilling fluid outlet in the separation tank to the liquid level of the drilling fluid for spraying; arranging a vacuum system in the separating tank, and pumping the separating tank to a negative pressure state through the vacuum system; the liquid level in the separation tank is kept stable through the cooling and liquid discharging system, the temperature of the drilling fluid in the cooling and liquid discharging system is reduced through the cooling mechanism, and hydrogen sulfide in the drilling fluid discharged to the solid control system is ensured to be within a safety standard range.
And a sulfur removal agent inlet and outlet is arranged at an inlet pipeline of the separation tank, and a sulfur removal agent is injected through a sulfur removal agent injection system to carry out sulfur removal treatment.
The method comprises the steps that a data monitoring and collecting system and a monitoring system are arranged, the data monitoring and collecting system monitors monitoring data in the hydrogen sulfide processing process in real time and transmits the monitored monitoring data to the monitoring system, and the monitoring system conducts real-time operation control on a heating system, a vacuum system, a cooling and liquid discharging system, a desulfurizing agent injection system, a stirring mechanism for stirring and disturbing fluid at the bottom of the drilling fluid and an injection system for pumping the drilling fluid at a drilling fluid outlet to the position of the liquid level of the drilling fluid for injection according to the monitored monitoring data.
The monitoring data comprises gas and liquid flow, pressure, temperature, hydrogen sulfide concentration, combustible gas concentration, drilling fluid density, drilling fluid PH value and drilling fluid level data.
The vacuum system is used for pumping the separation tank to a negative pressure state, and specifically comprises the following steps: and the sulfur-containing gas in the separation tank enters a gas-liquid separator under the suction action of a vacuum pump, after gas-liquid separation, the gas is pressurized and discharged to an outlet separation tank under the action of the vacuum pump, and the sulfur-containing gas is discharged to the outside of the vacuum system through an outlet at the top of the outlet separation tank for treatment.
The cooling water of the vacuum system enters the outlet separation tank through the cooling water inlet and the cooling water pipeline, one part of the cooling water of the outlet separation tank is injected into the vacuum pump through the cooling water loop, and the other part of the cooling water is discharged from the cooling water outlet on the outlet separation tank.
The vacuum system comprises two control processes, the data monitoring and acquisition system and the monitoring system monitor the vacuum degree in the separating tank, and the monitoring system controls the vacuum system to realize one-way or parallel operation.
Keep the liquid level steady in the knockout drum through cooling drainage system, specifically refer to: the drilling fluid separated by the separation tank enters a variable frequency pump through a pipeline, and is discharged through a variable frequency pump discharge pipeline; and monitoring the pipeline pressure of the cooling and drainage system and the concentration of hydrogen sulfide in the drilling fluid in real time, and if the concentration of the hydrogen sulfide in the discharged drilling fluid exceeds the standard, re-conveying the discharged drilling fluid through a loop to perform secondary separation in a separation tank.
The temperature of drilling fluid in the liquid discharge system is reduced through the cooling mechanism, and the concrete meaning is: the drilling fluid enters the cooling mechanism through a cooling and liquid discharging system pipeline, forms a winding structure in the cooling mechanism, and is discharged outside the cooling and liquid discharging system after being cooled.
The desulfurizing agent injection system is provided with a liquid storage tank, the desulfurizing agent is injected into an inlet pipeline of the separation tank through a delivery pump, and a filter and a switch valve are arranged in the delivery pipeline from the delivery pump to the inlet pipeline of the separation tank.
Compared with the prior art, the beneficial technical effects brought by the invention are as follows:
1. the separation efficiency of hydrogen sulfide in the drilling fluid is improved by adopting multiple technical measures of automatic temperature rise, mechanical turbulence, submerged injection and negative pressure extraction. The vacuum system is operated in a two-way parallel combination mode, the vacuum degree of the system is quickly and automatically adjusted in a combination mode of frequency conversion control and an adjusting valve, and continuous normal operation of the system is guaranteed. The liquid discharge system of the invention also adopts a two-way parallel combination mode to operate, adopts the frequency conversion control and the liquid level monitoring mechanism to realize the automatic adjustment of the liquid level in a linkage way, and ensures the stable measurement of the liquid level in the separation tank when the system operates. The cooling mechanism provided by the invention adopts a mode of combining air cooling and water cooling, so that the temperature of the drilling fluid is rapidly cooled, and the solubility of hydrogen sulfide in the drilling fluid is increased.
2. The invention has the unique advantages that the invention also adopts double emergency control measures, namely, the arranged liquid discharge branch circulation loop is opened emergently when the concentration of the hydrogen sulfide exceeds a set value, and simultaneously the concentration of the hydrogen sulfide in the drilling fluid is controlled by injecting the sulfur removal agent into the liquid inlet of the separation tank, thereby ensuring the safety of personnel and equipment.
3. According to the invention, the drilling fluid is subjected to temperature rise regulation in the separation tank through the drilling fluid heating system, the solubility of hydrogen sulfide is reduced under the influence of the temperature rise of the drilling fluid, and part of hydrogen sulfide gas is separated from the drilling fluid. The stirring mechanism is arranged in the tank, so that fluid at the bottom of the drilling fluid can be stirred and disturbed, and the separation of hydrogen sulfide gas in the high-viscosity drilling fluid is facilitated. Meanwhile, the underwater turbulent flow spraying mechanism is arranged in the middle of the tank, drilling fluid near a drilling fluid outlet in the tank is pumped to the bottom layer drilling fluid in the middle of the tank to be sprayed, and hydrogen sulfide of micro bubbles which are not easy to separate and are at the bottom of the drilling fluid can be circulated to the liquid level to be degassed and separated. The upper space in the tank is pumped to a negative pressure state by a vacuum system, so that the diameter of hydrogen sulfide bubbles in the drilling fluid is increased along with the reduction of pressure in the process of rising to the liquid level, the buoyancy is increased, and the rapid rising and separation of the bubbles are facilitated. The liquid discharge system of the hydrogen sulfide separation tank is set to operate in a two-way parallel combination mode, and the liquid level in the separation tank is automatically controlled and kept stable by adopting a frequency conversion technology. In order to ensure that the hydrogen sulfide in the drilling fluid discharged to the solid control system is at the lowest level, a cooling mechanism is arranged at an outlet of the liquid discharge system, so that the temperature of the drilling fluid is reduced, and the solubility of the hydrogen sulfide is improved.
Drawings
FIG. 1 is a process flow diagram of the present invention;
FIG. 2 is a schematic flow diagram of a vacuum system of the present invention;
FIG. 3 is a schematic flow diagram of the drainage system and cooling mechanism of the present invention;
FIG. 4 is a schematic flow diagram of a drilling fluid desulfurizing agent injection system of the present invention.
Detailed Description
Example 1
Referring to the attached fig. 1, this embodiment discloses:
a method for removing hydrogen sulfide in drilling fluid for drilling operation of a sulfur-containing stratum comprises the steps that the drilling fluid containing hydrogen sulfide returns out of a well, the drilling fluid enters a separation tank 104 after being subjected to pressure reduction, the drilling fluid entering the separation tank 104 is subjected to centrifugal separation, gas after the centrifugal separation is separated from the upper part of the separation tank 104, and the separated drilling fluid falls into the separation tank 104; the drilling fluid is subjected to temperature rise regulation through a drilling fluid heating system 113; stirring and disturbing fluid at the bottom of the drilling fluid in the separation tank 104; pumping the drilling fluid at the drilling fluid outlet in the separation tank to the liquid level of the drilling fluid for spraying; a vacuum system 111 is arranged in the separation tank, and the separation tank 104 is pumped to a negative pressure state through the vacuum system 111; the liquid level in the separation tank is kept stable through the cooling drainage system 106, the temperature of the drilling fluid in the cooling drainage system 106 is reduced through the cooling mechanism 110, and hydrogen sulfide in the drilling fluid discharged to the solid control system is ensured to be within a safety standard range.
Example 2
Referring to the attached fig. 1, this embodiment discloses:
a method for removing hydrogen sulfide in drilling fluid for drilling operation of a sulfur-containing stratum comprises the steps that the drilling fluid containing hydrogen sulfide returns out of a well, the drilling fluid enters a separation tank 104 after being subjected to pressure reduction, the drilling fluid entering the separation tank 104 is subjected to centrifugal separation, gas after the centrifugal separation is separated from the upper part of the separation tank 104, and the separated drilling fluid falls into the separation tank 104; the drilling fluid is subjected to temperature rise regulation through a drilling fluid heating system 113; stirring and disturbing fluid at the bottom of the drilling fluid in the separation tank 104; pumping the drilling fluid at the drilling fluid outlet in the separation tank 104 to the drilling fluid level for injection; a vacuum system 111 is arranged in the separation tank 104, and the separation tank is pumped to a negative pressure state through the vacuum system 111; the liquid level in the separation tank is kept stable through the cooling and draining system 106, the temperature of the drilling fluid in the cooling and draining system 106 is reduced through the cooling mechanism 110, and hydrogen sulfide in the drilling fluid discharged to the solid control system is ensured to be within a safety standard range; a sulfur removal agent inlet and outlet is arranged at the inlet pipeline of the separation tank 104, and a sulfur removal agent is injected through a sulfur removal agent injection system 107 for sulfur removal treatment;
the method comprises the steps that a data monitoring and acquiring system 115 and a monitoring system 108 are arranged, the data monitoring and acquiring system 115 monitors monitoring data in the hydrogen sulfide treatment process in real time and transmits the monitored monitoring data to the monitoring system 108, and the monitoring system 108 conducts real-time operation control on a heating system 113, a vacuum system 111, a cooling and liquid discharging system 106, a desulfurizing agent injection system 107, a stirring mechanism 112 for stirring and disturbing fluid at the bottom of the drilling fluid and an injection mechanism 101 for pumping the drilling fluid at a drilling fluid outlet to the position of the liquid level of the drilling fluid for injection according to the monitored monitoring data.
Example 3
Referring to the attached fig. 1, this embodiment discloses:
a method for removing hydrogen sulfide in drilling fluid for drilling operation of a sulfur-containing stratum comprises the steps that the drilling fluid containing hydrogen sulfide returns out of a well, the drilling fluid enters a separation tank 104 after being subjected to pressure reduction, the drilling fluid entering the separation tank 104 is subjected to centrifugal separation, gas after the centrifugal separation is separated from the upper part of the separation tank 104, and the separated drilling fluid falls into the separation tank 104; the drilling fluid is subjected to temperature rise regulation through a drilling fluid heating system 113; stirring and disturbing fluid at the bottom of the drilling fluid in the separation tank 104; pumping the drilling fluid at the drilling fluid outlet in the separation tank 104 to the drilling fluid level for injection; arranging a vacuum system 111 in the separating tank, and pumping the separating tank to a negative pressure state through the vacuum system 111; the liquid level in the separation tank is kept stable through the cooling and draining system 106, the temperature of the drilling fluid in the cooling and draining system 106 is reduced through the cooling mechanism 110, and hydrogen sulfide in the drilling fluid discharged to the solid control system is ensured to be within a safety standard range; a sulfur removal agent inlet and outlet is arranged at the inlet pipeline of the separation tank 104, and a sulfur removal agent is injected through a sulfur removal agent injection system 107 for sulfur removal treatment; the method comprises the steps that a data monitoring and acquiring system 115 and a monitoring system 108 are arranged, the data monitoring and acquiring system 115 monitors monitoring data in the hydrogen sulfide treatment process in real time and transmits the monitored monitoring data to the monitoring system 108, and the monitoring system 108 conducts real-time operation control on a heating system 113, a vacuum system 111, a cooling and liquid discharging system 106, a desulfurizing agent injection system 107, a stirring mechanism 112 for stirring and disturbing fluid at the bottom of the drilling fluid and an injection mechanism 101 for pumping the drilling fluid at a drilling fluid outlet to the position of the liquid level of the drilling fluid for injection according to the monitored monitoring data. The monitoring data comprises gas and liquid flow, pressure, temperature, hydrogen sulfide concentration, combustible gas concentration, drilling fluid density, drilling fluid PH value and drilling fluid level data.
The vacuum system 111 is used for pumping the separation tank 104 to a negative pressure state, specifically: the sulfur-containing gas in the separation tank 104 enters the gas-liquid separator 1 under the suction action of the vacuum pumps 4A and 4B, after gas-liquid separation, the gas is pressurized and discharged to the outlet separation tanks 5A and 5B under the action of the vacuum pumps 4A and 4B, and the sulfur-containing gas is discharged to the outside 14 of the vacuum system through outlets at the tops of the outlet separation tanks 5A and 5B for treatment; cooling water of the vacuum system 111 enters the outlet separation tanks 5A and 5B through the cooling water inlet 10 and the cooling water pipeline, one part of the cooling water of the outlet separation tanks 5A and 5B is injected into the vacuum pumps 4A and 4B through the cooling water loop, and the other part of the cooling water is discharged from the cooling water outlets 7A and 7B on the outlet separation tanks; the vacuum system comprises two control processes, the data monitoring and acquisition system and the monitoring system monitor the vacuum degree in the separating tank, and the monitoring system controls the vacuum system to realize one-way or parallel operation.
Example 4
Referring to the attached fig. 1, this embodiment discloses:
a method for removing hydrogen sulfide in drilling fluid for drilling operation of a sulfur-containing stratum comprises the steps that the drilling fluid containing hydrogen sulfide returns out of a well, the drilling fluid enters a separation tank 104 after being subjected to pressure reduction, the drilling fluid entering the separation tank 104 is subjected to centrifugal separation, gas after the centrifugal separation is separated from the upper part of the separation tank 104, and the separated drilling fluid falls into the separation tank 104; the drilling fluid is subjected to temperature rise regulation through a drilling fluid heating system 113; stirring and disturbing fluid at the bottom of the drilling fluid in the separation tank 104; pumping the drilling fluid at the drilling fluid outlet in the separation tank 104 to the drilling fluid level for injection; arranging a vacuum system 111 in the separating tank, and pumping the separating tank to a negative pressure state through the vacuum system 111; the liquid level in the separation tank is kept stable through the cooling and draining system 106, the temperature of the drilling fluid in the cooling and draining system 106 is reduced through the cooling mechanism 110, and hydrogen sulfide in the drilling fluid discharged to the solid control system is ensured to be within a safety standard range; a sulfur removal agent inlet and outlet is arranged at the inlet pipeline of the separation tank 104, and a sulfur removal agent is injected through a sulfur removal agent injection system 107 for sulfur removal treatment; the method comprises the steps that a data monitoring and acquiring system 115 and a monitoring system 108 are arranged, the data monitoring and acquiring system 115 monitors monitoring data in the hydrogen sulfide treatment process in real time and transmits the monitored monitoring data to the monitoring system 108, and the monitoring system 108 conducts real-time operation control on a heating system 113, a vacuum system 111, a cooling and liquid discharging system 106, a desulfurizing agent injection system 107, a stirring mechanism 112 for stirring and disturbing fluid at the bottom of the drilling fluid and an injection mechanism 101 for pumping the drilling fluid at a drilling fluid outlet to the position of the liquid level of the drilling fluid for injection according to the monitored monitoring data. The monitoring data comprises gas and liquid flow, pressure, temperature, hydrogen sulfide concentration, combustible gas concentration, drilling fluid density, drilling fluid PH value and drilling fluid level data.
The vacuum system 111 is used for pumping the separation tank 104 to a negative pressure state, specifically: the sulfur-containing gas in the separation tank 104 enters the gas-liquid separator 1 under the suction action of the vacuum pumps 4A and 4B, after gas-liquid separation, the gas is pressurized and discharged to the outlet separation tanks 5A and 5B under the action of the vacuum pumps 4A and 4B, and the sulfur-containing gas is discharged to the outside 14 of the vacuum system through outlets at the tops of the outlet separation tanks 5A and 5B for treatment; cooling water of the vacuum system 111 enters the outlet separation tanks 5A and 5B through the cooling water inlet 10 and the cooling water pipeline, one part of the cooling water of the outlet separation tanks 5A and 5B is injected into the vacuum pumps 4A and 4B through the cooling water loop, and the other part of the cooling water is discharged from the cooling water outlets 7A and 7B on the outlet separation tanks; the vacuum system comprises two control processes, a data monitoring and acquisition system and a monitoring system monitor the vacuum degree in the separating tank, and the monitoring system controls the vacuum system to realize one-way or parallel operation; the liquid level in the separation tank 104 is kept stable by a cooling drainage system 106, which specifically refers to: the drilling fluid separated by the separation tank 104 enters the variable frequency pump 205A through a pipeline, and is discharged through a discharge pipeline of the variable frequency pump 205A; monitoring the pipeline pressure of the cooling and drainage system 106 and the concentration of hydrogen sulfide in the drilling fluid in real time, and if the concentration of hydrogen sulfide in the discharged drilling fluid is monitored to exceed the standard, re-conveying the discharged drilling fluid through a loop to perform secondary separation in the separation tank 104; the temperature of the drilling fluid in the cooling drainage system 106 is reduced by the cooling mechanism 110, specifically: the drilling fluid enters the cooling mechanism 110 through the cooling drainage system 106, forms a convolute structure 2e in the cooling mechanism 110, and is discharged to the outside 212 of the cooling drainage system after being cooled; the desulfurizing agent injection system 107 is provided with a liquid storage tank 320, the desulfurizing agent is injected into an inlet pipeline of the separation tank 104 through a delivery pump 304, and a filter 302 and a switch valve 303 are arranged in a delivery pipeline from the delivery pump 304 to the inlet pipeline of the separation tank.
Example 5
Referring to fig. 1-4 of the specification, this embodiment discloses as another preferred embodiment of the present invention:
a method for removing hydrogen sulfide from drilling fluid in the drilling operation of a sulfur-containing stratum, wherein the drilling fluid containing hydrogen sulfide enters a separation tank 104 from a system inlet 105. After entering the tank, the drilling fluid first enters a high speed centrifuge bowl 114, as shown in FIG. 1. After centrifugal separation, the gas is separated from the upper part and the separated drilling fluid falls into the tank. The drilling fluid is subjected to temperature rise regulation through the drilling fluid heating system 113, the solubility of hydrogen sulfide is reduced under the influence of the temperature rise of the drilling fluid, and part of hydrogen sulfide gas is separated from the drilling fluid. The stirring mechanism 112 arranged in the tank can stir and disturb fluid at the bottom of the drilling fluid, and is beneficial to separation of hydrogen sulfide gas in the drilling fluid with high viscosity. The underwater turbulent flow injection mechanism 101 arranged in the tank pumps drilling fluid near a drilling fluid outlet in the tank to the drilling fluid at the bottom of the middle layer in the tank for injection, and can circulate hydrogen sulfide of micro bubbles which are not easy to separate at the bottom of the drilling fluid to the liquid level for degassing separation. The upper space in the tank is provided with a vacuum system 111 to pump the tank to a negative pressure state, so that the diameter of hydrogen sulfide bubbles in the drilling fluid is increased along with the reduction of pressure in the process of rising to the liquid level, and further the buoyancy is increased, thereby being beneficial to the rapid rising and separation of the bubbles. The cooling and drainage system 106 provided by the invention adopts a frequency conversion technology to automatically control and keep the liquid level in the separation tank stable, and reduces the temperature of the drilling fluid through the cooling mechanism, thereby improving the solubility of hydrogen sulfide and ensuring that the hydrogen sulfide in the drilling fluid discharged to the solid control system is at the lowest level. The inlet pipeline of the separating tank is provided with a desulfurizing agent injection port, and a desulfurizing agent can be injected in time for desulfurizing treatment through a desulfurizing agent injection system 107, so that the safety of personnel and equipment is ensured. The hydrogen sulfide removal system is provided with a data monitoring and acquisition system 115 which monitors all monitorable parameters of gas and liquid flow, pressure, temperature, hydrogen sulfide concentration, combustible gas concentration, drilling fluid density, drilling fluid pH value, liquid level and the like in the system in real time. The collected data may be directly transmitted to the centralized monitoring system 108, which may perform real-time operational control of the heating system, the agitation mechanism, the injection mechanism, the vacuum system, the cooling and draining system, and the sulfur removal agent injection system based on the monitored data.
The process flow of the vacuum system 111 of this embodiment is shown in fig. 2, which can rapidly pump the gas separated in the tank out of the tank, and automatically maintain the pressure of the air in the tank at the set negative pressure value. The vacuum system is realized by the following technical scheme: the sulfur-containing gas in the hydrogen sulfide separation tank 104 is sucked by the vacuum pumps 4A and 4B and enters the gas-liquid separator 1 through a pipeline a, and the gas-liquid separator 1 is provided with a monitoring mechanism 11 for pressure, concentration and the like. After gas-liquid separation, the gas enters the vacuum pumps 4A and 4B through pipelines c, d, c and k. The pipelines d and k are provided with check valves 2A and 2B and control switch valves 3A and 3B. Since the fluid discharged from the outlets of the vacuum pumps 4A and 4B includes cooling water and sulfur-containing gas, the gas is pressurized by the vacuum pumps and then discharged to the outlet separation tanks 5A and 5B through the pipes e and i. The sulfur-containing gas is discharged to the outside of the vacuum system 14 through pipelines f, m and g through outlets at the tops of the outlet separation tanks 5A and 5B for processing, and a flow monitoring mechanism 13 is arranged on the exhaust pipeline g. The cooling water separated by the separation tanks 5A and 5B returns to the vacuum pumps 4A and 4B again through the pipelines h and o to participate in cooling circulation, so that the water consumption is saved, and the operation safety of equipment is ensured. The vacuum system of the invention operates in a two-way parallel combination mode, and gas can enter the vacuum pump 4B through pipelines c and k. The pipeline k is provided with a check valve 2B and a control switch valve 3B. The vacuum pump 4B discharges the gas through line l to its outlet separator tank 5B. The gas is exhausted out of the vacuum system 14 through pipes m, g for processing. The cooling water separated by the separation tank 5B is returned to the vacuum pump 4B through the pipe o to participate in the cooling cycle. Cooling water in the vacuum system can be injected into the separation tanks 5A and 5B through the inlet 10 via pipes j and i controlled by valves 9 and 8A or via pipes j and n controlled by valves 9 and 8B, respectively, and the separation tanks are also provided with drain valves 7A and 7B, respectively. The two flows of the vacuum system can realize single-way or parallel operation by the automatic on-off control of the monitoring system 108 on the valves 3A, 3B, 6A and 6B. The vacuum system of the invention adopts the frequency conversion technology to carry out automatic control. When the monitoring mechanism 11 monitors that the vacuum degree in the hydrogen sulfide separation tank is lower than a set value, starting a vacuum pump and a pipeline system, and gradually increasing the operation frequency of the equipment until the vacuum degree is in the set value; when the vacuum degree exceeds a set value, the running frequency of the vacuum pump can be reduced, and meanwhile, the vacuum degree regulating valve 12 which is connected to the atmosphere through the pipeline b on the upper part of the automatic control gas-liquid separator 1 can be used for automatically and quickly regulating the vacuum degree, so that the system safety is ensured.
The process flow of the cooling and draining system 106 of the present invention is as shown in fig. 3, and is configured to operate in a two-way parallel combination mode, and the frequency conversion technology is adopted to automatically control and keep the liquid level in the drilling fluid separation tank 104 stable. The cooling mechanism is arranged, so that the temperature of the drilling fluid is reduced, and the solubility of hydrogen sulfide is improved. The vacuum system is realized by the following technical scheme: the drilling fluid separated by the separation tank 104 enters the variable frequency pump 205A through the pipeline 2a and is discharged through the pipeline 2 b. A drain valve 206A is provided on the pipe 2a to facilitate draining. The pipeline 2b is provided with a check valve 204A and a pressure detection mechanism 207A for real-time monitoring of the pipeline system pressure. If it is detected that there is any unseparated drilling fluid in the drainage fluid, valve 202A may be opened and the drained drilling fluid may be re-conveyed via line 2j back to the separation tank 104 for a second separation. Similarly, the other discharge line allows drilling fluid to pass through line 2k, enter variable frequency pump 205B, and exit via line 2 l. A waste valve 206B is provided in the line 2 k. The line 2l is provided with a check valve 204A and a pressure detection mechanism 207B. And valve 202B can be opened to re-deliver drilling fluid back to the separation tank 104 via line 2 m. The two-way flow can realize the operation of one way or parallel connection by the automatic switch control of the monitoring system 108 on the valves 201A, 201B, 203A and 203B. The discharged drilling fluid can be directly discharged out of the cooling and drainage system 212 through a pipeline 2c, and a flow monitoring mechanism 208 and a drain valve 221 are arranged on the pipeline 2 c. The drilling fluid may also be directed to the cooling mechanism 110 for cooling by control of valves 209, 211 and 213. The drilling fluid enters the cooling mechanism through the pipeline 2d, forms a convolute structure 2e in the cooling mechanism, and is discharged after being cooled. The cooling pump 215 is used in the cooling mechanism to spray cooling fluid from the nozzle 208 to the drilling fluid convolution 2e via the pipe 2 g. The heat generated by the cooling is exhausted through an exhaust system 216 at the top of the cooling mechanism. The drilling fluid temperature before and after cooling may be monitored by temperature monitoring mechanisms 210 and 214, respectively. The cooling liquid of the cooling means can be replenished from the environment 218 via the line 2f by opening the valve 217. Meanwhile, the cooling liquid of the cooling mechanism can be respectively conveyed to the variable frequency pumps 205A and 205B through the pump 219 by opening the valve 220 via the pipeline 2h to cool the pumps, and the liquid after heat exchange is conveyed back to the cooling mechanism 110 via the pipeline 2i, so that the circulating and efficient utilization of the cooling liquid is realized.
In the invention, two emergency safety control measures for the overproof hydrogen sulfide concentration are provided. Drilling fluid branch circulation loops 2j and 2m are arranged at an outlet of the liquid discharge system, and when volatile hydrogen sulfide gas still exists in the treated drilling fluid, the loops can be opened for circulation treatment; and a desulfurizing agent injection system 107 is additionally arranged, and a desulfurizing agent is injected in time at an inlet pipeline of the separation tank for desulfurizing treatment, so that the safety of personnel and equipment is ensured. The sulfur removal agent injection system is realized by the following technical scheme (see figure 4): the injection system is provided with a reservoir tank 320 and the sulphur removal agent is injected by a transfer pump 304 via lines 3a and 3b into the inlet line of the separation system. The line 3a is provided with a filter 302 and an on-off valve 303. A check valve 307 and an on-off valve 306 are provided in the line 3 b. The pressure on the injection line is monitored by the pressure monitoring mechanism 308, and when a set value is exceeded, the sulfur removing agent can be injected into the reservoir 320 through the line 3c by opening the valve 309. The reservoir tank 320 is provided with a relief valve 310 and a liquid level metering mechanism 311. The loading and unloading mechanism of the liquid storage tank is integrally arranged, namely when loading is needed, valves 317 and 318 are closed, a pump 315 is opened, valves 313 and 316 are opened, the sulfur removing agent 312 enters the tank through pipelines 3d, 3e, 3f and 3g, and a filter 314 is arranged on a liquid inlet pipeline; when discharge is required, valves 313 and 316 are closed, valves 317 and 318 are opened, pump 315 is opened, and the sulfur removal agent in storage tank 320 is removed via lines 3g, 3h, 3e and 3i to the outside 319.
In the present invention, all valves, instruments, pumps, devices, etc. can be controlled by centralized control or other known means. The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, but rather as the subject matter of the invention is to be construed as broadly as the appended claims.
Claims (7)
1. The method for removing hydrogen sulfide in the drilling fluid for the drilling operation of the sulfur-containing stratum is characterized by comprising the following steps of: returning the drilling fluid containing hydrogen sulfide out of the well, reducing the pressure of the drilling fluid, then feeding the drilling fluid into a separation tank, centrifugally separating the drilling fluid fed into the separation tank, separating gas obtained after centrifugal separation from the upper part of the separation tank, and enabling the separated drilling fluid to fall into the separation tank; heating and adjusting the drilling fluid through a drilling fluid heating system; stirring and disturbing fluid at the bottom of the drilling fluid in the separation tank; pumping the drilling fluid at the drilling fluid outlet in the separation tank to the position below the liquid level of the drilling fluid for injection; arranging a vacuum system in the separating tank, and pumping the separating tank to a negative pressure state through the vacuum system; the liquid level in the separation tank is kept stable through the cooling and liquid discharging system, the temperature of the drilling fluid in the cooling and liquid discharging system is reduced through the cooling mechanism, and hydrogen sulfide in the drilling fluid discharged to the solid control system is ensured to be within a safety standard range; a desulfurizing agent inlet and outlet is arranged at an inlet pipeline of the separation tank, and a desulfurizing agent is injected through a desulfurizing agent injection system for desulfurizing treatment; the method comprises the following steps that a data monitoring and acquiring system and a monitoring system are arranged, the data monitoring and acquiring system monitors monitoring data in a hydrogen sulfide treatment process in real time and transmits the monitored monitoring data to the monitoring system, and the monitoring system carries out real-time operation control on a heating system, a vacuum system, a cooling and liquid discharging system, a desulfurizing agent injection system, a stirring mechanism for stirring and disturbing fluid at the bottom of drilling fluid and an injection system for pumping the drilling fluid at a drilling fluid outlet to the position below the liquid level of the drilling fluid for injection according to the monitored monitoring data;
the liquid level in the separation tank is kept stable through the cooling and liquid discharging system, and the method specifically comprises the following steps: the drilling fluid separated by the separation tank enters a variable frequency pump through a pipeline, and is discharged through a variable frequency pump discharge pipeline; and monitoring the pipeline pressure of the cooling and drainage system and the concentration of hydrogen sulfide in the drilling fluid in real time, and if the concentration of the hydrogen sulfide in the discharged drilling fluid is monitored to exceed the standard, re-conveying the discharged drilling fluid to a separation tank through a loop for secondary separation.
2. The method of claim 1 for removing hydrogen sulfide from a drilling fluid used in drilling a sulfur-bearing formation, comprising: the monitoring data includes gas and liquid flow, pressure, temperature, hydrogen sulfide concentration, drilling fluid density, drilling fluid PH, and drilling fluid level data.
3. The method of claim 1 for removing hydrogen sulfide from a drilling fluid used in drilling a sulfur-bearing formation, comprising: the vacuum system is used for pumping the separation tank to a negative pressure state, and specifically comprises the following steps: and the sulfur-containing gas in the separation tank enters a gas-liquid separator under the suction action of a vacuum pump, after gas-liquid separation, the gas is pressurized and discharged to an outlet separation tank under the action of the vacuum pump, and the sulfur-containing gas is discharged to the outside of the vacuum system through an outlet at the top of the outlet separation tank for treatment.
4. The method of claim 3 for removing hydrogen sulfide from a drilling fluid used in drilling a sulfur-bearing formation, comprising: the cooling water of the vacuum system enters the outlet separation tank through the cooling water inlet and the cooling water pipeline, one part of the cooling water of the outlet separation tank is injected into the vacuum pump through the cooling water loop, and the other part of the cooling water is discharged from the cooling water outlet on the outlet separation tank.
5. The method for removing hydrogen sulfide from a drilling fluid in a drilling operation for a sulfur-containing formation according to claim 1 or 3, wherein: the vacuum system comprises two control processes, the data monitoring and acquisition system and the monitoring system monitor the vacuum degree in the separating tank, and the monitoring system controls the vacuum system to realize one-way or parallel operation.
6. The method of claim 1 for removing hydrogen sulfide from a drilling fluid used in drilling a sulfur-bearing formation, comprising: the temperature of drilling fluid in the liquid discharge system is reduced through the cooling mechanism, and the concrete meaning is: the drilling fluid enters the cooling mechanism through a cooling and liquid discharging system pipeline, forms a winding structure in the cooling mechanism, and is discharged outside the cooling and liquid discharging system after being cooled.
7. The method of claim 1 for removing hydrogen sulfide from a drilling fluid used in drilling a sulfur-bearing formation, comprising: the desulfurizing agent injection system is provided with a liquid storage tank, the desulfurizing agent is injected into an inlet pipeline of the separation tank through a delivery pump, and a filter and a switch valve are arranged in the delivery pipeline from the delivery pump to the inlet pipeline of the separation tank.
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| CN110331951B (en) * | 2019-06-28 | 2021-07-23 | 中国石油集团川庆钻探工程有限公司 | Method for removing hydrogen sulfide in oil-based drilling fluid by using basic zinc carbonate aqueous solution |
| CN111140227A (en) * | 2019-11-06 | 2020-05-12 | 中国石油集团川庆钻探工程有限公司 | Rapid logging rock debris collecting method for closed drilling circulation system of sulfur-containing stratum |
| CN111140189A (en) * | 2019-11-06 | 2020-05-12 | 中国石油集团川庆钻探工程有限公司 | Quick logging rock debris collecting system of closed drilling circulation system of sulfur-containing stratum |
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| GB1218195A (en) * | 1967-08-28 | 1971-01-06 | Black Sivalls & Bryson Inc | Process for removing hydrogen sulphide from a gas stream and converting it to elemental sulphur |
| JPS5017318B1 (en) * | 1970-12-29 | 1975-06-19 | ||
| CN101463713A (en) * | 2009-01-13 | 2009-06-24 | 中国石油集团川庆钻探工程有限公司钻采工艺技术研究院 | Drilling fluid circulating and separating method for sulfur-containing stratum under-balance drilling operation |
| CN101525993B (en) * | 2009-03-18 | 2012-10-10 | 中国石油集团川庆钻探工程有限公司 | Method for monitoring and controlling hydrogen sulfide in sulfur-containing stratum underbalanced drilling |
| GB2523488B (en) * | 2011-07-15 | 2016-02-10 | Nat Oilwell Varco Lp | Apparatus and method for separating solids from a solids laden drilling mud |
| CN204671943U (en) * | 2015-03-10 | 2015-09-30 | 丁帆 | A kind of circulation type gas-liquid separator |
| CN205805455U (en) * | 2016-05-31 | 2016-12-14 | 中石化石油工程技术服务有限公司 | Compound logging rotation free of discontinuities lift-type degassing cylinder |
| CN205840827U (en) * | 2016-08-08 | 2016-12-28 | 成都瑞奇石化工程股份有限公司 | Oil gas field waste liquid high efficiency separation processing system |
| CN206064127U (en) * | 2016-09-18 | 2017-04-05 | 中海油（天津）管道工程技术有限公司 | A kind of reaction unit of hypergravity medicament cyclic absorption hydrogen sulfide |
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Effective date of registration: 20200907 Address after: 100007 Beijing, Dongzhimen, North Street, No. 9, No. Co-patentee after: CNPC Chuanqing Drilling Engineering Co.,Ltd. Patentee after: CHINA NATIONAL PETROLEUM Corp. Address before: The 1 section of No. 3 company Chuanqing Drilling Technology Information Office Chenghua District Green Road 610051 Chengdu City, Sichuan Province Patentee before: CNPC Chuanqing Drilling Engineering Co.,Ltd. |