15 results about "Sour gas" patented technology

The utility model relates to the field of oil and gas exploitation, in particular to a blowout pool for a sulfur-containing gas well, which comprises a combustion cylinder, an ignition system and a spraying system. And the combustion cylinder is arranged in the blowout pool body and is communicated with the tail end of the blowout pipeline. The ignition system comprises a spark plug, and the spark plug is located above the combustion cylinder. The spraying system comprises a spraying pipe, the spraying pipe is located above the open flow pool body, the spraying pipe is used for spraying alkaline liquid, and the spraying range of the spraying pipe can cover the whole open flow pool body. The spraying system capable of spraying the alkaline liquid is arranged above the blowout pool body, so that the alkaline liquid and hydrogen sulfide gas leaked from the combustion cylinder are subjected to neutralization reaction, and leakage and diffusion of the hydrogen sulfide gas can be effectively reduced.

A method for preparing a gas sweetening system for less shutdown time is provided. The method includes stopping a sour gas feed to a gas sweetening system, and raising the set point for a temperature of a lean amine cooler to about 150° F. The H2S concentration in a lean amine is monitored. The preparation of the gas sweetening system for maintenance is completed when the H2S concentration reaches a target value.

The utility model relates to the reaction equipment of resource utilization to sour gas, specifically square reactor, reactor square casing inside is divided into process gas heating area and process gas reaction area in proper order from below to top, and the upper of reactor square casing is process gas reheating area, and the reactor square casing of process gas heating area is equipped with process gas inlet connector, and the heat exchanger is located process gas inlet connector top, and the heat exchanger is by the multilayer of from below to top setting, and each layer is at least one, the reactor square casing of process gas reaction area is installed with catalyst support frame, and the catalyst support frame is placed with catalyst, and process gas reheating area is equipped with combustion furnace and expansion joint, and the lower part of combustion furnace is connected with reactor square casing, and the top of combustion furnace is connected with expansion joint. The utility model improves the overall processing capacity of equipment, reduces equipment land occupation while expanding device scale.

The invention discloses a phase change absorbent for selectively removing hydrogen sulfide as well as a preparation method and application thereof, and the phase change absorbent comprises the following components in percentage by mass: 20-45% of cyclic amide tertiary amine, 5-10% of a catalyst, 1-5% of a catalyst, 1-5% of a catalyst and the balance of a solvent. 20%-50% of a hydrogen bond reconstruction type phase separation accelerant; and the balance of water. The molecular structure of the cyclic amide tertiary amine comprises a tertiary amine nitrogen atom used for carrying out acid-base reaction with H2S and an amide group used as a hydrogen bond acceptor, and the cyclic amide tertiary amine is used for reacting with H2S with high selectivity; the hydrogen bond reconstruction type phase separation accelerant is polyhydric alcohol containing two or more hydroxyl groups, after H2S is absorbed, an absorbent is induced to be subjected to liquid-liquid phase separation, a rich phase rich in H2S and a lean phase low in H2S content are formed, and then separation of the rich phase and the lean phase can be achieved through simple gravity or centrifugation. The phase change absorbent provided by the invention has the advantages of high H2S absorption selectivity, low regeneration energy consumption, simple preparation method and low operation cost, and is especially suitable for fine desulfurization of refinery dry gas and other complex acidic gases.

A method of scavenging hydrogen sulfide from a sour gas well includes injecting a nanoemulsion through a borehole into a subterranean geological formation including a gaseous hydrocarbon composition including hydrogen sulfide. The nanoemulsion includes a mineral oil, water, a surfactant, and an additive. The water is a continuous phase of the nanoemulsion. The surfactant is selected from a group consisting of a sodium dodecylbenzenesulfonate, a cetyltrimethylammonium bromide, and a nonionic polyoxyethylene detergent. The additive is selected from a group consisting of a silver salt and a copper salt. The method includes circulating the nanoemulsion in the borehole in the subterranean geological formation to contact the nanoemulsion with the hydrocarbon composition and reacting the nanoemulsion with the hydrogen sulfide in the gaseous hydrocarbon composition to form a production gas including less than 5 parts per million (ppm) of hydrogen sulfide.

The invention relates to an alcohol amine rich solution regeneration system and method integrated with a second-class absorption heat pump, and the system comprises a regeneration tower and a steam reboiler, and also comprises the second-class absorption heat pump; a circulating steam inlet II and a circulating steam outlet II of the regeneration tower are connected with the second-class absorption heat pump through a circulating heat medium pipeline; a circulating heat medium in the circulating heat medium pipeline is alcohol amine barren liquor extracted from the bottom of the regeneration tower. As an alternative scheme, the alkylol amine rich solution regeneration system further comprises a waste heat recovery reboiler; the waste heat recovery reboiler is connected with a circulating steam inlet II and a circulating steam outlet II of the regeneration tower and the second-class absorption heat pump; and a circulating heat medium in the circulating heat medium pipeline is water. The invention aims to efficiently and stably recover the low-temperature waste heat at the top of the regeneration tower rich in acid gas, and improve the low-temperature waste heat into high-grade heat energy capable of meeting the requirements of a reboiler, so that the net energy consumption in the regeneration process is systematically reduced, and the corrosion and control problems caused by the net energy consumption are solved.

The utility model discloses a gas chromatograph for acid gas analysis. The gas chromatograph comprises a sample introduction system, a separation system and a thermal conductivity detector, the sample introduction system and the thermal conductivity detector are connected to the separation system; the separation system comprises a first separation system and a second separation system which are arranged in parallel; a ten-way valve is arranged in each of the first separation system and the second separation system; the ten-way valve of the first separation system is connected with the ten-way valve of the second separation system through a pipeline, the ten-way valve of one separation system is connected with a sample injection system, and the ten-way valve of the other separation system is connected with an external recovery system; and the first separation system and the second separation system are respectively connected with a thermal conductivity detector. According to the gas chromatograph, the analysis of H2, O2, N2, CH4, CO, CO2, H2S, COS and SO2 in the acid gas can be completed within 10 minutes through one-time sample injection, the situation that the analysis result is inaccurate due to system errors caused by multiple times of sample injection is avoided, the time for an operator to make contact with a sample is shortened, and occupational health safety is effectively provided.

The invention relates to the technical field of data analysis, and discloses a shaft and pipe network production allocation risk assessment system for a sulfur-containing gas reservoir, and the system comprises an integrated model which comprises a gas reservoir model, a shaft model and a pipe network model; the configuration module is used for configuring configuration parameters of the integrated model and inputting simulated production allocation value parameters of each production node; a storage module; the extraction module is used for extracting the production allocation result of the integrated model stored in the storage module; the early warning judgment module is used for comparing the production allocation result with configuration parameters so as to judge whether early warning is carried out or not; the sulfur deposition judgment module is used for calculating the sulfur solubility according to the production allocation result and comparing the sulfur solubility with the actual sulfur content so as to judge whether to give an early warning or not; and the display module is used for displaying the configuration result and the judgment results of the early warning judgment module and the sulfur deposition judgment module. The safety and feasibility of the production allocation scheme can be improved.

A method for removing hydrogen sulfide (H2S) from a H2S-containing gas composition, including charging an aqueous media to a reactor under continuous agitation, dispersing particles of a composite in the aqueous media to form a composite mixture, continuously agitating the composite mixture, introducing the H2S-containing gas composition to the reactor containing the composite mixture under continuous agitation and passing the H2S-containing gas composition through the composite mixture, and adsorbing and removing H2S from the gas composition by the composite mixture to form a purified gas composition. The composite contains a CuMnAl layered triple oxide (LTO) and zeolitic imidazolate framework-8 (ZIF-8) nanoparticles. The ZIF-67 nanoparticles are dispersed between layers of the CuMnAl LTO.

The application discloses a phase change absorbent for selectively removing hydrogen sulfide and a preparation method and application thereof. The phase change absorbent comprises the following components in mass fraction: 20-45% of a cyclic amide tertiary amine; 20-50% of a hydrogen bond reformation phase separation promoter; and the balance of water. The cyclic amide tertiary amine contains a tertiary amine nitrogen atom for acid-base reaction with H2S and an amide group as a hydrogen bond acceptor in a molecular structure, and is used for high-selectivity reaction with H2S. The hydrogen bond reformation phase separation promoter is a polyhydric alcohol containing two or more hydroxyl groups, and can induce liquid-liquid phase separation of the absorbent after absorbing H2S, so as to form a rich phase rich in H2S and a lean phase with less H2S content, and then the separation of the rich phase and the lean phase can be realized through simple gravity or centrifugation. The phase change absorbent has the advantages of high H2S absorption selectivity, low regeneration energy consumption, simple preparation method and low operation cost, and is particularly suitable for fine desulfurization of complex sour gas such as refinery dry gas.

The utility model relates to a recovery device especially relates to a hydrogenation device sulfur-containing dry gas recovery device. The utility model provides such a hydrogenation device sulfur-containing dry gas recovery device, including installation frame, gravity settling tank, cyclone separator, feed pipe etc. ; The gravity settling tank and cyclone separator are equipped in the installation frame, the gravity settling tank right side is equipped with the feed pipe, the gravity settling tank top has opened the first gas outlet, the gravity settling tank bottom is equipped with the connecting pipe, the one end of connecting pipe far away from the gravity settling tank is connected with water pump, water pump water delivery end is connected in cyclone separator rear side top. The utility model gravity settling tank separates big granule droplet preferentially, and cyclone separator further captures tiny droplet, and double effect significantly promotes the liquid efficiency of removing, satisfies the processing demand of large -scale, high water content sulfur-containing dry gas.

Without any restriction on the maximum hardness of the surface layer, provided is a high strength steel plate for sour gas apparatuses having, excellent SSCC resistance in an environment equivalent to ISO-15156 Region 2 where pH is 3.5 or more and the H2S partial pressure is 0.003 bar to 1 bar. The high strength steel plate for sour gas apparatuses having a chemical composition containing, in mass%, specified amounts of C, Si, Mn, P, S, N, Al, and Ca, Ni of 0.10 % to 4.00 %, and at least one selected from the group consisting of Cr, Mo, W, and Nb in a specified amount, with the balance being Fe and inevitable impurities, in which a ratio HVmin / HVmax of the minimum value HVmin to the maximum value HVmax of Vickers hardness HV0.1 at 0.25 mm below a surface of the steel plate is 0.77 or more.

The utility model discloses an acid flue gas treatment tower with a precooling function, which belongs to the technical field of environmental protection equipment, and comprises a tower body, a precooling area, a gas-liquid contact area and a demisting area are respectively arranged in the tower body from bottom to top, a top tower is arranged above the demisting area, and the top tower is connected with the gas-liquid contact area. A smoke exhaust pipe is arranged in the middle of the upper part of the top tower; the pre-cooling area and the coil pipe type pre-cooler are arranged in the tower body, so that in-situ pre-cooling of high-temperature acidic flue gas in the tower is realized. The flue gas is effectively cooled before entering the core reaction area, so that the evaporation rate of the absorption liquid is remarkably reduced, the gas-liquid contact time is prolonged, and the solubility and reaction rate of the acid gas in the absorption liquid are improved, thereby greatly improving the removal efficiency. Meanwhile, as the evaporation loss is reduced, the required liquid-gas ratio is reduced, the consumption of the alkaline absorbent is reduced, and the operation cost is reduced.

A method of removing hydrogen sulfide from a subterranean geological formation includes injecting a drilling fluid suspension in the subterranean geological formation. The drilling fluid suspension has a pH of 10 or more and includes a layered triple hydroxide material, including manganese, zinc, and iron, in an amount of 0.01 to 0.5 precent by weight of the drilling fluid suspension. The method further includes circulating the drilling fluid suspension in the subterranean geological formation and forming a water-based mud and scavenging the hydrogen sulfide from the subterranean geological formation by reacting the hydrogen sulfide with the layered triple hydroxide material in the water-based mud.

The invention discloses a method for calculating the bottom hole pressure of a deep sulfur-containing gas well, which belongs to the technical field of oil and gas exploitation, and is characterized by comprising the following steps of: a, explaining and acquiring the middle pressure of a gas well production layer; b, drawing the gas well static pressure and the gas well shut-in wellhead pressure into a gas well static pressure calculation chart, and fitting a gas well static pressure calculation formula; c, drawing the flow pressure of the gas well with the water-gas ratio smaller than 0.7 into the flow pressure calculation chart of the gas well with the small water-gas ratio, and fitting a flow pressure calculation formula of the gas well; d, drawing the flow pressure of the gas well with the water-gas ratio larger than 0.7 into the flow pressure calculation chart of the gas well with the large water-gas ratio, and fitting a flow pressure gradient calculation formula of the gas well; and e, firstly evaluating the gas well and the water-gas well, and then calculating and solving the middle pressure of the gas well production layer according to the wellhead oil pressure, the shut-in oil pressure and the well depth data. According to the method, the gas reservoir underground pressure can be mastered in real time and accurately judged, the testing risk of well testing is effectively reduced, and continuous production of a gas field is guaranteed.