CN110596318A - Method for determining total yield of hydrogen sulfide in oil well - Google Patents
Method for determining total yield of hydrogen sulfide in oil well Download PDFInfo
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- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 title claims abstract description 266
- 229910000037 hydrogen sulfide Inorganic materials 0.000 title claims abstract description 266
- 239000003129 oil well Substances 0.000 title claims abstract description 96
- 238000000034 method Methods 0.000 title claims abstract description 56
- 239000012071 phase Substances 0.000 claims abstract description 134
- 239000007789 gas Substances 0.000 claims abstract description 78
- 238000004519 manufacturing process Methods 0.000 claims abstract description 28
- 238000012360 testing method Methods 0.000 claims abstract description 28
- 239000008346 aqueous phase Substances 0.000 claims abstract description 22
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 71
- 239000003921 oil Substances 0.000 claims description 56
- 239000010779 crude oil Substances 0.000 claims description 32
- 239000007788 liquid Substances 0.000 claims description 27
- 230000019086 sulfide ion homeostasis Effects 0.000 claims description 24
- QAOWNCQODCNURD-UHFFFAOYSA-N Sulfuric acid Chemical compound OS(O)(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-N 0.000 claims description 12
- 239000012530 fluid Substances 0.000 claims description 8
- 229910052739 hydrogen Inorganic materials 0.000 claims description 7
- 239000001257 hydrogen Substances 0.000 claims description 7
- 229910001410 inorganic ion Inorganic materials 0.000 claims description 5
- 238000000926 separation method Methods 0.000 claims description 5
- 238000011161 development Methods 0.000 claims description 4
- RBTBFTRPCNLSDE-UHFFFAOYSA-N 3,7-bis(dimethylamino)phenothiazin-5-ium Chemical compound C1=CC(N(C)C)=CC2=[S+]C3=CC(N(C)C)=CC=C3N=C21 RBTBFTRPCNLSDE-UHFFFAOYSA-N 0.000 claims description 2
- 229960000907 methylthioninium chloride Drugs 0.000 claims description 2
- 238000002798 spectrophotometry method Methods 0.000 claims description 2
- 125000004435 hydrogen atom Chemical class [H]* 0.000 claims 1
- 238000011282 treatment Methods 0.000 abstract description 21
- 239000003814 drug Substances 0.000 abstract description 12
- 230000007613 environmental effect Effects 0.000 abstract description 3
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 7
- 229910052717 sulfur Inorganic materials 0.000 description 7
- 239000011593 sulfur Substances 0.000 description 7
- 238000012937 correction Methods 0.000 description 6
- 230000000694 effects Effects 0.000 description 6
- 239000003795 chemical substances by application Substances 0.000 description 5
- 230000003009 desulfurizing effect Effects 0.000 description 5
- 150000002431 hydrogen Chemical class 0.000 description 5
- 238000005070 sampling Methods 0.000 description 5
- 238000011272 standard treatment Methods 0.000 description 5
- 239000000126 substance Substances 0.000 description 4
- 238000005067 remediation Methods 0.000 description 3
- 239000009671 shengli Substances 0.000 description 3
- 238000007796 conventional method Methods 0.000 description 2
- 238000000605 extraction Methods 0.000 description 2
- 238000005191 phase separation Methods 0.000 description 2
- 239000002699 waste material Substances 0.000 description 2
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 1
- 238000011276 addition treatment Methods 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000009792 diffusion process Methods 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 230000000737 periodic effect Effects 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 238000004073 vulcanization Methods 0.000 description 1
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Abstract
The invention belongs to the technical field of safe production and environmental protection, and particularly relates to a method for determining the total yield of hydrogen sulfide in an oil well. The method specifically comprises the following steps: measuring the content of gas-phase hydrogen sulfide in the test oil well; determining the content of aqueous phase hydrogen sulfide in the test oil well: determining the content of hydrogen sulfide in the oil phase; determining the yield of gas phase hydrogen sulfide; determining the yield of aqueous phase hydrogen sulfide; determination of the production of hydrogen sulfide from the oil phase the total production of hydrogen sulfide from the test wells was determined. The method not only considers the gas-phase hydrogen sulfide, but also considers the water-phase hydrogen sulfide and the oil-phase hydrogen sulfide, more accurately reflects the actual situation of the total amount of the oil well hydrogen sulfide, and provides reliable basis for the source management of the oil well hydrogen sulfide; the standard-reaching treatment period of the hydrogen sulfide is shortened by over 60 percent, the standard-reaching rate of the oil well hydrogen sulfide dosing treatment is improved, and potential safety hazards are reduced; effectively reduces the medicine adding amount and saves the medicine adding cost by 30 percent.
Description
Technical Field
The invention belongs to the technical field of safe production and environmental protection, and particularly relates to a method for determining the total yield of hydrogen sulfide in an oil well.
Background
With the continuous development of water injection development and heavy oil thermal recovery, a large number of high-sulfur-content hydrogen sulfide oil wells appear in a plurality of oil fields, and 4000 more hydrogen sulfide-content oil wells are counted. With the continuous improvement of safety production and environmental protection requirements, the source treatment of hydrogen sulfide is developed in a plurality of oil fields, and the mode of adding a liquid desulfurizer to an oil well mouth is mainly adopted. A desulfurizing agent is continuously or periodically added through an oil well casing, the desulfurizing agent diffuses to the bottom of a well along the oil casing annulus and reacts with hydrogen sulfide in oil well produced liquid in a contact manner (at the moment, the pressure is higher due to the fact that the desulfurizing agent is positioned at the bottom of the well with the depth of 1000-2000 m, the pressure is usually 10-20 MPa, most of associated gas is dissolved in the produced liquid), the hydrogen sulfide is eliminated at the bottom of the well, and source treatment of the hydrogen sulfide is achieved.
The main steps of the existing oil well hydrogen sulfide chemical dosing treatment are as follows: (1) the hydrogen sulfide content before treatment was measured. Sampling the oil well associated gas at a sampling gate of the produced liquid of the oil well wellhead, and determining the content of hydrogen sulfide in the associated gas; (2) determining the adding amount of the desulfurizer. Roughly estimating and determining the adding amount of the desulfurizer according to the hydrogen sulfide content of the associated gas and the sulfur capacity of the desulfurizer; (3) and (5) adding medicine into the sleeve. Adding a desulfurizing agent in a continuous dropwise adding or periodic adding manner; (4) adjusting the dosage. Periodically measuring the content of hydrogen sulfide in the wellhead associated gas, and adjusting the dosage according to the measurement result to ensure that the content of the hydrogen sulfide in the treated wellhead associated gas is lower than 30mg/m3And the requirement of safe production of the oil well is met.
There are two problems in the above dosing management process: (1) the basis for the calculation of hydrogen sulfide is rather small. In the treatment process, only the content of hydrogen sulfide in associated gas is taken as a calculation basis, the hydrogen sulfide dissolved in the produced liquid of the oil well is not considered, and because a large amount of hydrogen sulfide is dissolved in the produced liquid under the temperature and the pressure of a well head, the content of the hydrogen sulfide is smaller; (2) the dosage and the treatment effect can not be fed back in time, which causes the problems of treatment not reaching the standard or large dosage and medicament waste. The volume of the oil collar aerial oil well produced liquid and associated gas is large and can reach 10-20 m generally3The added desulfurizing agent is generally not more than 0.1m3And d, the volume difference between the two is very different, no special mixing equipment is arranged underground, the distribution of the desulfurizer is realized only by means of bottom hole flow of produced liquid and diffusion of the desulfurizer, and the time from adding the desulfurizer to uniformly distributing the desulfurizer in the oil sleeve annular liquid generally needs 1-2 weeks. When the dosage is adjusted according to the determination result of hydrogen sulfide in the wellhead associated gas, the time of 1-2 weeks is needed. In the current treatment mode, the optimal dosage for reaching the standard treatment needs to be determined for one oil well containing hydrogen sulfide, and the time is at least 1 month. The problems of substandard hydrogen sulfide treatment or large dosage and medicament waste exist in the process.
If in the treatment process, the total yield of the hydrogen sulfide in the oil well can be accurately determined, and the chemical adding amount of the desulfurizer is determined according to the total yield, the standard-reaching treatment period can be greatly shortened, the standard-reaching rate of the wellhead hydrogen sulfide is improved, the safety risk of the hydrogen sulfide-containing well is reduced, and the chemical adding treatment cost is saved.
Disclosure of Invention
The invention provides a method for determining the total yield of hydrogen sulfide in an oil well, aiming at the defects of the existing oil well hydrogen sulfide dosing treatment method. The method finally determines a calculation formula of the total hydrogen sulfide yield of the oil well based on simple and easily-measured parameters such as gas-phase hydrogen sulfide content, temperature, pressure, liquid amount and the like according to the basic principle of gas-liquid balance, provides an accurate calculation basis for the addition of the desulfurizer, and solves the problems of low well mouth standard reaching rate, potential safety hazard, large addition amount, high treatment cost and the like in the existing hydrogen sulfide addition treatment process.
The invention discloses a method for determining the total yield of hydrogen sulfide in an oil well, which is characterized by comprising the following steps of:
(1) measuring the content of gas-phase hydrogen sulfide in a test oil well, wherein the content is recorded as f and the unit ppm;
(2) determining the content of water-phase hydrogen sulfide in a test oil well, and specifically comprising the following steps:
firstly, taking the produced liquid of a test oil well and the water sample after oil-water separation, measuring the solubility of hydrogen sulfide in the water phase under normal pressure (0.1MPa) at different temperatures, and using cwNote, unit kg/m3；
Secondly, drawing a change curve of the solubility of the hydrogen sulfide in the water phase along with the temperature, and obtaining the solubility c of the hydrogen sulfide in the water phase under normal pressure through regression fittingwTemperature t is related to: c. Cw＝a·t-m(R2≥0.99)；
Obtaining the content of the hydrogen sulfide dissolved in the water phase under different temperatures, pressures and gas-phase hydrogen sulfide contents according to Henry's laww(t，P，f)＝a·P·f·t-m101325, wherein P is pressure in MPa; secondly, considering the influence of factors of dissolved oil, dissolved gas and inorganic ions in the actually produced water, the content of the dissolved hydrogen sulfide in the water is in cw(t，P，f)Is modified to c on the basis ofw(t，P，f，x)＝x·cw(t，P，f)＝x·a·P·f·t-mValue range of/101325, x0.8 to 1.2.
(3) Determination of hydrogen sulfide content in oil phase
Taking the crude oil dehydrated and degassed in the oil well, measuring the solubility of hydrogen sulfide in the crude oil under normal pressure (101325Pa) and different temperatures, and calculating the solubility as coNote, unit kg/m3(ii) a Drawing a change curve of the oil phase hydrogen sulfide solubility along with the temperature, and obtaining the hydrogen sulfide solubility c in the oil phase under normal pressure through regression fittingoRelation c with temperature to＝b·t-n(R2Not less than 0.99), according to Henry's law, obtaining the content c of the dissolved hydrogen sulfide in the oil phase under different temperature, pressure and gas phase hydrogen sulfide contento(t，P，f)＝b·P·f·t-n101325; secondly, considering the influence of emulsified water and dissolved gas in the crude oil, the content of dissolved hydrogen sulfide in the crude oil is CoIs modified to c on the basis ofo(t，P，f，y)＝y.b·P·f·t-nThe value range of y is 0.8-1.5.
(4) Determining the yield of gas phase hydrogen sulfide
The yield of the gas phase hydrogen sulfide is the product of the yield of the oil well associated gas and the content of the gas phase hydrogen sulfide, and is W1＝Q·f×10-6In units kg/d, wherein: w1The yield of gas phase hydrogen sulfide is unit kg/d; q is the oil well associated gas yield in Nm3D; f is the content of gaseous hydrogen sulfide in ppm.
(5) Determination of the yield of aqueous Hydrogen sulfide
The yield of aqueous phase hydrogen sulfide is the product of the yield of water and the content of aqueous phase hydrogen sulfide, and is W2＝L·ω·cw(t，P，f，x)＝L·ω·x·a·P·f·t-m101325 in kg/d. Wherein: w2For the yield of aqueous hydrogen sulfide, unit m3D; l is the oil well fluid production, m3D; omega is the water content of the produced liquid.
(6) Determination of the yield of oil phase hydrogen sulfide
The yield of hydrogen sulfide in the oil phase is the product of the yield of crude oil and the content of hydrogen sulfide in the crude oil, and is W3＝L·(1-ω)·co(t，P，f，y)＝L·(1-ω)·y·b·P·f·t-n/101325
Wherein: w3Is the yield of oil phase hydrogen sulfide
(7) Determination of the Total production of Hydrogen sulfide from test oil wells
Total yield of oil well hydrogen sulfide-gas phase hydrogen sulfide production + water phase hydrogen sulfide production + oil phase hydrogen sulfide production, Wt＝W1+W2+W3
Wt＝Q·f×10-6+L·ω·x·a·P·f·t-m/101325+L·(1-ω)·y·b·P·f·t-n/101325
＝f·[Q+9.87L·ω·x·a·P·t-m+9.87L·(1-ω)·y·b·P·t-n]×10-6
Wherein WtThe total production of hydrogen sulfide for the oil well is in kg/d.
Wherein the method for measuring the content of the gas-phase hydrogen sulfide in the step (1) adopts a colorimetric tube method, and the content is determined according to the color development length of the colorimetric tube.
Wherein the solubility of the aqueous phase hydrogen sulfide in the step (2) is determined by methylene blue spectrophotometry.
Wherein the solubility of the hydrogen sulfide in the crude oil in the step (3) is determined by an iodometry method.
Wherein the associated gas yield in the step (4) is provided by a gas-liquid two-phase separation metering device.
Wherein the liquid volume L in the step (5) is provided by gas-liquid two-phase separation metering equipment, and the water content is measured by an automatic water content analyzer.
Compared with the prior art, the invention has the following advantages:
(1) the method not only considers the gas-phase hydrogen sulfide, but also considers the water-phase hydrogen sulfide and the oil-phase hydrogen sulfide, more accurately reflects the actual situation of the total amount of the oil well hydrogen sulfide, and provides reliable basis for the source management of the oil well hydrogen sulfide;
(2) the method can combine the existing oil well production parameters by only measuring the content of the gas-phase hydrogen sulfide, quickly determine the total amount of the oil well hydrogen sulfide, and is convenient and quick;
(3) the method shortens the standard-reaching treatment period of the hydrogen sulfide by over 60 percent, improves the standard-reaching rate of the chemical treatment of the hydrogen sulfide in the oil well, and reduces the potential safety hazard;
(4) the method of the invention effectively reduces the dosage and saves the dosage cost by 30 percent.
Drawings
FIG. 1 illustrates the conventional method for treating well A with hydrogen sulfide;
FIG. 2 is a graph of hydrogen sulfide solubility in water phase of well A as a function of temperature;
FIG. 3 is a graph of hydrogen sulfide solubility in water phase from well A as a function of temperature;
FIG. 4 shows a hydrogen sulfide remediation process for well A using the method of the present invention;
FIG. 5 shows the hydrogen sulfide remediation process for well B using conventional methods;
FIG. 6 is a graph of hydrogen sulfide solubility in water phase from well B as a function of temperature;
FIG. 7 is a graph of hydrogen sulfide solubility in water phase from well B as a function of temperature;
FIG. 8 shows a hydrogen sulfide remediation process for well B using the method of the present invention;
FIG. 9 is a graph of hydrogen sulfide solubility in water phase from well C as a function of temperature;
FIG. 10 is a graph of hydrogen sulfide solubility in the water phase of well C as a function of temperature.
Detailed Description
The technical solution of the present invention will be further described with reference to the following specific examples.
Example 1
Typical oil well A in a certain block of the Shengli oil field, and the daily liquid production amount is 30m3Water content 86%, associated gas content 66Nm3And d, the well head temperature is 55 ℃, and the pressure is 0.55 MPa.
The estimation of the well hydrogen sulfide yield is carried out by adopting a traditional method, the product of gas quantity and gas-phase hydrogen sulfide content is 1700 x 60 x 1.5/1000000 x 0.15kg/d, if the sulfur capacity of the desulfurizer is 1.2%, the theoretical adding quantity of the well desulfurizer is 0.15/1.2% x 12.5kg/d, the desulfurizer is initially added according to 12.5kg/d, after 10 days of adding, the hydrogen sulfide content is reduced to 1200ppm and is not reduced, in order to achieve the standard, the medicine quantity is increased to 50kg/d, the hydrogen sulfide content is reduced to below 20ppm after 10 days, in order to save the medicine quantity, the medicine quantity is reduced to 25kg/d, the hydrogen sulfide content is increased to 300ppm after 5 days, the medicine quantity is insufficient, the medicine quantity is increased to 35kg/d again, the hydrogen sulfide content is gradually reduced to below 20ppm, the safety requirement is reached, the process lasts for about 60 days, wherein the time of not reaching the standard reaches 45 days (figure 1), and great potential safety hazard exists for personnel and equipment of an oil extraction and gathering system.
The method for determining the total yield of the hydrogen sulfide in the oil well comprises the following specific steps:
(1) determination of the content of gaseous hydrogen sulfide in the test oil well
The gas phase hydrogen sulfide content of the oil well A is 1700ppm through testing.
(2) Determination of the content of aqueous hydrogen sulfide in the test oil well
Taking a water sample obtained after oil-water separation of liquid extracted from the oil well A, measuring the solubility of hydrogen sulfide in the water phase at different temperatures under normal pressure (101325Pa), and recording the solubility in cw in kg/m3(ii) a The solubility of hydrogen sulfide in the aqueous phase was plotted as a function of temperature (FIG. 2).
Obtaining the solubility c of hydrogen sulfide in the water phase under normal pressure by regression fittingwTemperature t is related to: c. Cw＝51.68·t-0.84(R2＝0.9982)。
According to Henry's law, the content of hydrogen sulfide dissolved in the water phase under different temperature, pressure and gas phase hydrogen sulfide content is obtained as follows:
cw(t，P，f)＝51.68·P·f·t-0.84/101325
＝5.1·P·f·t-0.79×10-4。
wherein P is the pressure of a sampling test point at the wellhead in unit of MPa; secondly, considering the influence of factors of dissolved oil, dissolved gas and inorganic ions in the actually produced water, the content of hydrogen sulfide in the water phase is in cw(t，P，f)The correction is as follows:
cw(t，P，f，x)＝x·cw(t，P，f)＝5.1×0.8·P·f·t-0.84×10-4
＝4.08·P·f·t-0.84×10-4and x is 0.8.
(3) Determination of the hydrogen sulfide content of the oil phase
Taking the crude oil dehydrated and degassed in the oil well, measuring the solubility of hydrogen sulfide in the crude oil under normal pressure (101325Pa) and different temperatures, and calculating the solubility as coNote, unit kg/m3(ii) a The oil phase hydrogen sulfide solubility was plotted as a function of temperature (fig. 3).
Obtaining the solubility c of the hydrogen sulfide in the oil phase under normal pressure through regression fittingoRelation c with temperature to＝11.6·t-1.25(R20.998), according to henry's law, the content of hydrogen sulfide dissolved in the oil phase at different temperatures, pressures and gas phase hydrogen sulfide contents is obtained as:
co(t，P，f)＝11.6·P·f·t-1.25/101325
＝1.14·P·f·t-1.25×10-4
secondly, considering the influence of emulsified water and dissolved gas in the crude oil, the content of dissolved hydrogen sulfide in the crude oil is coThe correction is as follows:
co(t，P，f，y)＝y·co(t，P，f)
＝1.4×1.14·P·f·t-1.25×10-4
＝1.6·P·f·t-1.25×10-4and y has a value of 1.4.
(4) Determining the yield of gas phase hydrogen sulfide
The yield of the gas phase hydrogen sulfide is the product of the yield of the oil well associated gas and the content of the gas phase hydrogen sulfide, and is W1＝Q·f×10-6In units kg/d, wherein: w1The yield of gas phase hydrogen sulfide is unit kg/d; q is the oil well associated gas yield in Nm3D; f is the content of gaseous hydrogen sulfide in ppm.
(5) Determination of the yield of aqueous Hydrogen sulfide
The yield of aqueous phase hydrogen sulfide is the product of the yield of water and the content of aqueous phase hydrogen sulfide, and is W2＝L·ω·cw(t，P，f，x)＝4.08·L·ω·P·f·t-0.84×10-4In units of kg/d.Wherein: w2For the yield of aqueous hydrogen sulfide, unit m3D; l is the oil well fluid production, m3D; omega is the water content of the produced liquid.
(6) Determination of the yield of oil phase hydrogen sulfide
The yield of hydrogen sulfide in the oil phase is the product of the yield of crude oil and the content of hydrogen sulfide in the crude oil, and is
W3＝L·(1-ω)·co(t，P，f，y)＝1.6L·(1-ω)·P·f·t-1.25×10-4
Wherein: w3Is the yield of oil phase hydrogen sulfide.
(7) Determination of the Total production of Hydrogen sulfide from test oil wells
Total yield of oil well hydrogen sulfide-gas phase hydrogen sulfide production + water phase hydrogen sulfide production + oil phase hydrogen sulfide production, Wt＝W1+W2+W3
Wt＝Q·f×10-6+4.08L·ω·P·f·t-0.84×10-4+1.6L·(1-ω)·P·f·t-1.25×10-4＝f·[Q+408L·ω·P·t-0.84+160L·(1-ω)·P·t-1.25]×10-6。
For well A, the daily fluid production was 30m3Water content 86%, associated gas content 60Nm3And d, when the wellhead temperature is 55 ℃, the pressure is 0.55MPa, and the content of gas-phase hydrogen sulfide is 1700ppm, calculating by using the formula to obtain the total hydrogen sulfide yield of the well as follows:
Wt＝f·[Q+408L·ω·P·t-0.84+160L·(1-ω)·P·t-1.25]×10-6
＝0.38kg/d。
the sulfur capacity of the desulfurizer is 1.2%, the theoretical adding amount of the desulfurizer in the well is 31.7kg/d from 0.38/1.2%, the desulfurizer is added according to the amount, the content of wellhead hydrogen sulfide is stably reduced to be below 20ppm after 10d, the standard treatment period is only 10d (figure 4), and table 1 shows the effect comparison of the two treatment methods.
TABLE 1 comparison of the effects of the two treatment methods
As can be seen from table 1: the standard treatment period is shortened from 60d to 10d, the period is shortened by 83.3 percent, and the effect is obvious compared with the traditional method.
Example 2
The daily liquid yield of an oil well B in a certain block of the Shengli oil field is 30m3Water content 90%, associated gas content 90Nm3And d, the well head temperature is 65 ℃, and the pressure is 0.7 MPa.
The estimation of the well hydrogen sulfide yield is carried out by adopting a traditional method, the product of gas quantity and gas-phase hydrogen sulfide content is 2500 x 90 x 1.5/1000000 x 0.34kg/d, if the sulfur capacity of the desulfurizer is 1.2%, the theoretical adding quantity of the well desulfurizer is 0.34/1.2% x 28.3kg/d, after 12d of the desulfurizer is initially added according to 28.3kg/d, the hydrogen sulfide content is reduced to 900ppm and is not reduced, in order to reach the standard, the medicine quantity is increased to 60kg/d, after 13d, the hydrogen sulfide content is reduced to about 400ppm and is not reduced, the medicine quantity is increased to 80kg/d again, after 9d, the hydrogen sulfide content is reduced to 20ppm, the safety requirement is met, the process lasts for about 40d, the time of reaching the standard is up to 35d, and a large safety hazard exists to oil extraction and gathering system personnel and equipment (figure 5).
The method for determining the total yield of the hydrogen sulfide in the oil well comprises the following specific steps:
(1) determination of the content of gaseous hydrogen sulfide in the test oil well
The gas phase hydrogen sulfide content of the oil well B is 2500ppm through testing.
(2) Determination of the content of aqueous hydrogen sulfide in the test oil well
Taking a water sample obtained after oil-water separation of liquid produced by the well B, measuring the solubility of hydrogen sulfide in the water phase at different temperatures under normal pressure (101325Pa) to obtain cwNote, unit kg/m3(ii) a The solubility of hydrogen sulfide in the aqueous phase was plotted as a function of temperature (FIG. 5).
Obtaining the solubility c of hydrogen sulfide in the water phase under normal pressure by regression fittingwTemperature t is related to: c. Cw＝46.24·t-0.79(R2＝0.9975)；
According to Henry's law, the content of hydrogen sulfide dissolved in the water phase under different temperature, pressure and gas phase hydrogen sulfide content is obtained
cw(t，P，f)＝46.24·P·f·t-0.79/101325
＝4.56·P·f·t-0.79×10-4
Wherein P is the pressure of a sampling test point at the wellhead in unit of MPa; secondly, considering the influence of factors of dissolved oil, dissolved gas and inorganic ions in the actually produced water, the content of hydrogen sulfide in the water phase is in cw(t，P，f)The correction is as follows:
cw(t，P，f，x)＝x·cw(t，P，f)
＝4.56×0.9·P·f·t-0.792×10-4
＝4.1·P·f·t-0.792×10-4and x is 0.9.
(3) Determination of the hydrogen sulfide content of the oil phase
Taking the crude oil dehydrated and degassed in the oil well, measuring the solubility of hydrogen sulfide in the crude oil under normal pressure (101325Pa) and different temperatures, and calculating the solubility as coNote, unit kg/m3(ii) a The oil phase hydrogen sulfide solubility was plotted as a function of temperature (fig. 6).
Obtaining the solubility c of the hydrogen sulfide in the oil phase under normal pressure through regression fittingoRelation c with temperature to＝28.18·t-1.52(R20.9931) according to henry's law, the content of dissolved hydrogen sulfide in the oil phase at different temperatures, pressures and gas phase hydrogen sulfide contents is:
co(t，P，f)＝28.18·P·f·t-1.52/101325＝2.78·P·f·t-1.52×10-4(ii) a Secondly, considering the influence of emulsified water and dissolved gas in the crude oil, the content of dissolved hydrogen sulfide in the crude oil is coOn the basis of the correction of
co(t，P，f，y)＝y·co(t，P，f)＝1.2×2.78·P·f·t-1.52×10-4
＝3.34·P·f·t-1.52×10-4And y has a value of 1.2.
(4) Determining the yield of gas phase hydrogen sulfide
The yield of the gas phase hydrogen sulfide is the product of the yield of the oil well associated gas and the content of the gas phase hydrogen sulfide, and is W1＝Q·f×10-6In units kg/d, wherein: w1The yield of gas phase hydrogen sulfide is unit kg/d; q is the oil well associated gas yield in Nm3D; f is the content of gaseous hydrogen sulfide in ppm.
(5) Determination of the yield of aqueous Hydrogen sulfide
The yield of aqueous phase hydrogen sulfide is the product of the yield of water and the content of aqueous phase hydrogen sulfide, and is W2＝L·ω·cw(t，P，f，x)＝4.1·L·ω·P·f·t-0.79×10-4In units of kg/d. Wherein: w2For the yield of aqueous hydrogen sulfide, unit m3D; l is the oil well fluid production, m3D; omega is the water content of the produced liquid.
(6) Determination of the yield of oil phase hydrogen sulfide
The yield of hydrogen sulfide in the oil phase is the product of the yield of crude oil and the content of hydrogen sulfide in the crude oil, and is:
W3＝L·(1-ω)·co(t，P，f，y)
＝3.34L·(1-ω)·P·f·t-1.52×10-4
wherein: w3Is the yield of oil phase hydrogen sulfide.
(7) Determination of the Total production of Hydrogen sulfide from test oil wells
Total yield of oil well hydrogen sulfide-gas phase hydrogen sulfide production + water phase hydrogen sulfide production + oil phase hydrogen sulfide production, Wt＝W1+W2+W3
Wi＝Q·f×10-6+4.1L·ω·P·f·t-0.79×10-4+3.34L·(1-ω)·P·f·t-1.52×10-4＝f·[Q+410L·ω·P·t-0.79+334L·(1-ω)·P·t-1.52]×10-6
For well B, daily fluid production is 30m3Water content 90%, associated gas content 90Nm3D, when the well mouth temperature is 65 ℃, the pressure is 0.7MPa and the gas phase hydrogen sulfide content is 2500ppm, calculating the vulcanization of the well by using the formulaThe total hydrogen production is:
W＝f·[Q+410L·ω·P·t-0.79+334L·(1-ω)·P·t-1.52]×10-6
＝0.94kg/d。
the sulfur capacity of the desulfurizer is 1.2%, the theoretical adding amount of the desulfurizer in the well is 0.94/1.2% ═ 78.3kg/d, the desulfurizer is added according to the amount, the content of the wellhead hydrogen sulfide is stably reduced to be below 20ppm after 13d, and the substandard period is only 13 d.
TABLE 2 comparison of the effects of the two treatments
As can be seen from table 2: the standard treatment period is shortened from 40d to 13d, the period is shortened by 67.5 percent, and the effect is obvious compared with the traditional method.
Example 3
Oil well C in certain area of Shengli oil field, daily liquid production capacity 60m394% of water content and 110Nm of associated gas volume3And d, well head temperature 85 ℃ and pressure 1.0 MPa.
The estimation of the well hydrogen sulfide yield is carried out by adopting a traditional method, the product of the gas quantity and the gas-phase hydrogen sulfide content is 20000 × 110 × 1.5/1000000 × 3.3kg/d, if the sulfur capacity of the desulfurizer is 1.2%, the theoretical adding quantity of the well desulfurizer is 3.3/1.2% and 275kg/d, the desulfurizer is added according to the dosage, only the hydrogen sulfide can be treated to 17000ppm, and after 3 times of adjustment, the adding quantity is increased to 1800kg/d, the hydrogen sulfide is stably controlled below 20ppm, and the process lasts 55d, wherein the time length of reaching the standard is 40 d.
The method for determining the total yield of the hydrogen sulfide in the oil well comprises the following specific steps:
(1) determination of the content of gaseous hydrogen sulfide in the test oil well
The test results show that the content of the gas phase hydrogen sulfide of the oil well B is 20000 ppm.
(2) Determination of the content of aqueous hydrogen sulfide in the test oil well
Taking a water sample obtained after oil-water separation of the liquid produced by the well C, and determining that the normal pressure (101325Pa) is not higherSolubility of hydrogen sulfide in aqueous phase at the same temperature, in cwNote, unit kg/m3(ii) a The solubility of hydrogen sulfide in the aqueous phase was plotted as a function of temperature (FIG. 9).
Obtaining the solubility c of hydrogen sulfide in the water phase under normal pressure by regression fittingwTemperature t is related to: c. Cw＝35.32·t-0.71(R2＝0.9949)；
According to Henry's law, the content of hydrogen sulfide dissolved in the water phase under different temperature, pressure and gas phase hydrogen sulfide content is obtained as follows:
cw(t，P，f)＝35.32·P·f·t-0.71/101325
＝3.49·P·f·t-0.71×10-4
wherein P is the pressure of a sampling test point at the wellhead in unit of MPa; secondly, considering the influence of factors of dissolved oil, dissolved gas and inorganic ions in the actually produced water, the content of hydrogen sulfide in the water phase is in cw(t，P，f)The correction is as follows:
cw(t，P，f，x)＝x·cw(t，P，f)＝3.49×1.1·P·f·t-0.71×10-4
＝3.84·P·f·t-0.71×10-4and x is 1.1.
(3) Determination of the hydrogen sulfide content of the oil phase
Taking the crude oil dehydrated and degassed in the oil well, measuring the solubility of hydrogen sulfide in the crude oil under normal pressure (101325Pa) and different temperatures, and calculating the solubility as coNote, unit kg/m3(ii) a The oil phase hydrogen sulfide solubility was plotted as a function of temperature (fig. 10).
Obtaining the solubility c of the hydrogen sulfide in the oil phase under normal pressure through regression fittingoRelation c with temperature to＝4.01·t-0.9(R20.9974), according to henry's law, the content of hydrogen sulfide dissolved in the oil phase at different temperatures, pressures and gas phase hydrogen sulfide contents is obtained as:
co(t，P，f)＝4.01·P·f·t-0.9/101325
＝3.96·P·f·t-0.9×10-5
secondly, considering the influence of emulsified water and dissolved gas in the crude oil, the content of dissolved hydrogen sulfide in the crude oil is coThe correction is as follows:
co(t，P，f，y)＝y·co(t，P，f)＝0.9×3.96·P·f·t-0.9×10-5
＝3.56·P·f·t-0.9×10-5and y is 0.9.
(4) Determining the yield of gas phase hydrogen sulfide
The yield of the gas phase hydrogen sulfide is the product of the yield of the oil well associated gas and the content of the gas phase hydrogen sulfide, and is W1＝Q·f×10-6In units kg/d, wherein: w1The yield of gas phase hydrogen sulfide is unit kg/d; q is the oil well associated gas yield in Nm3D; f is the content of gaseous hydrogen sulfide in ppm.
(5) Determination of the yield of aqueous Hydrogen sulfide
The yield of aqueous phase hydrogen sulfide is the product of the yield of water and the content of aqueous phase hydrogen sulfide, and is W2＝L·ω·cw(t，P，f，x)＝3.84·L·ω·P·f·t-0.71×10-4In units of kg/d. Wherein: w2For the yield of aqueous hydrogen sulfide, unit m3D; l is the oil well fluid production, m3D; omega is the water content of the produced liquid.
(6) Determination of the yield of oil phase hydrogen sulfide
The yield of hydrogen sulfide in the oil phase is the product of the yield of crude oil and the content of hydrogen sulfide in the crude oil, and is W3＝L·(1-ω)·co(t，P，f，y)＝3.56L·(1-ω)·P·f·t-0.9×10-5Wherein: w3Is the yield of oil phase hydrogen sulfide
(7) Determination of the Total production of Hydrogen sulfide from test oil wells
Total yield of oil well hydrogen sulfide-gas phase hydrogen sulfide production + water phase hydrogen sulfide production + oil phase hydrogen sulfide production, Wt＝W1+W2+W3
Wt＝Q·f×10-6+3.84L·ω·P·f·t-0.71×10-4+3.56L·(1-ω)·P·f·t-0.9×10-5＝f·[Q+384L·ω·P·t-0.71+35.6L·(1-ω)·P·t-0.9]×10-6
For well C, the daily fluid production is 60m394% of water content and 110Nm of associated gas volume3And d, when the well head temperature is 85 ℃, the pressure is 1.0MPa, and the gas-phase hydrogen sulfide content is 20000ppm, calculating the total hydrogen sulfide yield of the well by using the formula:
W＝f·[Q+384L·ω·P·t-0.71+35.6L·(1-ω)·P·t-0.9]×10-6
＝20.75kg/d。
the sulfur capacity of the desulfurizer is 1.2 percent, the theoretical adding amount of the desulfurizer in the well is 20.75/1.2 percent to 1729kg/d, the desulfurizer is added according to the dosage, and the hydrogen sulfide is stably reduced from 20000ppm to below 20ppm only after 10 d.
Compared with the traditional method, the method provided by the invention reduces the standard treatment period from 55d to 10d, shortens the period by 81.8%, and greatly reduces the safety risk.
Claims (10)
1. A method for determining the total hydrogen sulfide production of an oil well is characterized by comprising the following steps:
(1) measuring the content of gas-phase hydrogen sulfide in the test oil well;
(2) determining the content of aqueous phase hydrogen sulfide in the test oil well:
(3) determining the content of hydrogen sulfide in the oil phase;
(4) determining the yield of gas phase hydrogen sulfide;
(5) determining the yield of aqueous phase hydrogen sulfide;
(6) determining the yield of oil phase hydrogen sulfide;
(7) the total production of hydrogen sulfide from the test wells was determined.
2. The method for determining the total hydrogen sulfide production of the oil well as claimed in claim 1, wherein the step of determining the content of the hydrogen sulfide in the water phase in the test oil well comprises the following steps:
firstly, taking test oil well produced liquid and water sample after oil-water separation, determining normal pressure(0.1MPa) solubility of hydrogen sulfide in aqueous phase at different temperatures, in cwNote, unit kg/m3；
Secondly, drawing a change curve of the solubility of the hydrogen sulfide in the water phase along with the temperature, and obtaining the solubility c of the hydrogen sulfide in the water phase under normal pressure through regression fittingwTemperature t is related to: c. Cw＝a·t-m(R2≥0.99)；
Obtaining the content of the hydrogen sulfide dissolved in the water phase under different temperatures, pressures and gas-phase hydrogen sulfide contents according to Henry's laww(t，P，f)＝a·P·f·t-m101325, wherein P is pressure in MPa; secondly, considering the influence of factors of dissolved oil, dissolved gas and inorganic ions in the actually produced water, the content of the dissolved hydrogen sulfide in the water is in cw(t，P，f)Is modified to c on the basis ofw(t，P，f，x)＝x·cw(t，P，f)＝x·a·P·f·t-mThe value range of x is 0.8-1.2.
3. The method for determining the total hydrogen sulfide production of an oil well as claimed in claim 2, wherein the step of determining the hydrogen sulfide content in the oil phase comprises the following steps: taking the crude oil dehydrated and degassed in the oil well, measuring the solubility of hydrogen sulfide in the crude oil under normal pressure (101325Pa) and different temperatures, and calculating the solubility as coNote, unit kg/m3(ii) a Drawing a change curve of the oil phase hydrogen sulfide solubility along with the temperature, and obtaining the hydrogen sulfide solubility c in the oil phase under normal pressure through regression fittingoRelation c with temperature to＝b·t-n(R2Not less than 0.99), according to Henry's law, obtaining the content c of the dissolved hydrogen sulfide in the oil phase under different temperature, pressure and gas phase hydrogen sulfide contento(t，P，f)＝b·P·f·t-n101325; secondly, considering the influence of emulsified water and dissolved gas in the crude oil, the content of dissolved hydrogen sulfide in the crude oil is CoIs modified to c on the basis ofo(t，P，f，y)＝y·b·P·f·t-nThe value range of y is 0.8-1.5.
4. The method for determining total oil well hydrogen sulfide production according to claim 1,the method is characterized in that the method for determining the yield of the gas-phase hydrogen sulfide comprises the following specific steps: the yield of the gas phase hydrogen sulfide is the product of the yield of the oil well associated gas and the content of the gas phase hydrogen sulfide, and is W1＝Q·f×10-6In units kg/d, wherein: w1The yield of gas phase hydrogen sulfide is unit kg/d; q is the oil well associated gas yield in Nm3D; f is the content of gaseous hydrogen sulfide in ppm.
5. The method for determining total hydrogen sulfide production from oil well according to claim 1, wherein the step of determining the production of aqueous phase hydrogen sulfide comprises the following steps: the yield of aqueous phase hydrogen sulfide is the product of the yield of water and the content of aqueous phase hydrogen sulfide, and is W2＝L·ω·cw(t，P，f，x)＝L·ω·x·a·P·f·t-m101325 in kg/d. Wherein: w2For the yield of aqueous hydrogen sulfide, unit m3D; l is the oil well fluid production, m3D; omega is the water content of the produced liquid.
6. The method for determining the total hydrogen sulfide production of an oil well according to claim 3, wherein the step of determining the production of the oil-phase hydrogen sulfide comprises the following steps: the yield of hydrogen sulfide in the oil phase is the product of the yield of crude oil and the content of hydrogen sulfide in the crude oil, and is W3＝L·(1-ω)·co(t，P，f，y)＝L·(1-ω)·y·b·P·f·t-n101325, wherein: w3Is the yield of oil phase hydrogen sulfide.
7. The method for determining the total hydrogen sulfide production of the oil well according to claim 1, wherein the step of determining the total hydrogen sulfide production of the test oil well comprises the following steps: total yield of oil well hydrogen sulfide-gas phase hydrogen sulfide production + water phase hydrogen sulfide production + oil phase hydrogen sulfide production, Wt＝W1+W2+W3
Wt＝Q·f×10-6+L·ω·x·a·P·f·t-m/101325+L·(1-ω)·y·b·P·f·t-n/101325
＝f·[Q+9.87L·ω·x·a·P·t-m+9.87L·(1-ω)·y·b·P·t-n]×10-6
Wherein WtThe total production of hydrogen sulfide for the oil well is in kg/d.
8. The method for determining the total yield of hydrogen sulfide from oil well according to claim 1, wherein the method for determining the content of hydrogen sulfide from gas phase is a colorimetric tube method, and the content is determined according to the color development length of the colorimetric tube.
9. The method for determining total production of hydrogen sulfide from oil well according to claim 1, wherein the solubility of hydrogen sulfide in aqueous phase is determined by methylene blue spectrophotometry.
10. The method for determining total hydrogen sulfide production from oil well according to claim 1, wherein the solubility of hydrogen sulfide in crude oil is determined by iodometry.
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