CN114198060B - Method for treating sulfur deposition in shaft of ultra-deep sulfur-containing gas well - Google Patents
Method for treating sulfur deposition in shaft of ultra-deep sulfur-containing gas well Download PDFInfo
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- CN114198060B CN114198060B CN202010898699.3A CN202010898699A CN114198060B CN 114198060 B CN114198060 B CN 114198060B CN 202010898699 A CN202010898699 A CN 202010898699A CN 114198060 B CN114198060 B CN 114198060B
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- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 title claims abstract description 329
- 229910052717 sulfur Inorganic materials 0.000 title claims abstract description 300
- 239000011593 sulfur Substances 0.000 title claims abstract description 300
- 230000008021 deposition Effects 0.000 title claims abstract description 148
- 238000000034 method Methods 0.000 title claims abstract description 53
- 239000002904 solvent Substances 0.000 claims abstract description 116
- 239000007788 liquid Substances 0.000 claims abstract description 33
- 238000006073 displacement reaction Methods 0.000 claims abstract description 20
- 238000007711 solidification Methods 0.000 claims abstract description 18
- 230000008023 solidification Effects 0.000 claims abstract description 18
- 238000010587 phase diagram Methods 0.000 claims abstract description 15
- 229910000831 Steel Inorganic materials 0.000 claims abstract description 12
- 238000004364 calculation method Methods 0.000 claims abstract description 12
- 239000010959 steel Substances 0.000 claims abstract description 12
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 claims description 33
- WQOXQRCZOLPYPM-UHFFFAOYSA-N dimethyl disulfide Chemical compound CSSC WQOXQRCZOLPYPM-UHFFFAOYSA-N 0.000 claims description 24
- 238000004519 manufacturing process Methods 0.000 claims description 23
- AVXURJPOCDRRFD-UHFFFAOYSA-N Hydroxylamine Chemical compound ON AVXURJPOCDRRFD-UHFFFAOYSA-N 0.000 claims description 11
- 229920001281 polyalkylene Polymers 0.000 claims description 11
- 230000000694 effects Effects 0.000 claims description 10
- 239000000203 mixture Substances 0.000 claims description 9
- 230000008016 vaporization Effects 0.000 claims description 8
- 238000009834 vaporization Methods 0.000 claims description 7
- 239000007864 aqueous solution Substances 0.000 claims description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 5
- 230000009471 action Effects 0.000 claims description 4
- 238000005259 measurement Methods 0.000 claims description 3
- 238000002347 injection Methods 0.000 claims 1
- 239000007924 injection Substances 0.000 claims 1
- 239000002994 raw material Substances 0.000 claims 1
- 230000000630 rising effect Effects 0.000 claims 1
- 230000015572 biosynthetic process Effects 0.000 abstract description 9
- 238000005086 pumping Methods 0.000 abstract description 6
- 238000002791 soaking Methods 0.000 abstract description 4
- 238000007599 discharging Methods 0.000 abstract description 3
- 230000008569 process Effects 0.000 abstract description 3
- 230000009286 beneficial effect Effects 0.000 abstract description 2
- 238000006243 chemical reaction Methods 0.000 abstract description 2
- 238000001556 precipitation Methods 0.000 abstract description 2
- 239000007789 gas Substances 0.000 description 137
- 230000000052 comparative effect Effects 0.000 description 19
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 13
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 13
- 238000010276 construction Methods 0.000 description 11
- 238000004090 dissolution Methods 0.000 description 10
- 239000003112 inhibitor Substances 0.000 description 9
- 230000007797 corrosion Effects 0.000 description 6
- 238000005260 corrosion Methods 0.000 description 6
- 239000000126 substance Substances 0.000 description 6
- 238000010438 heat treatment Methods 0.000 description 5
- 230000008018 melting Effects 0.000 description 5
- 238000002844 melting Methods 0.000 description 5
- 230000001105 regulatory effect Effects 0.000 description 5
- 239000003054 catalyst Substances 0.000 description 4
- 230000003647 oxidation Effects 0.000 description 4
- 238000007254 oxidation reaction Methods 0.000 description 4
- 239000007790 solid phase Substances 0.000 description 4
- UHOVQNZJYSORNB-UHFFFAOYSA-N Benzene Chemical compound C1=CC=CC=C1 UHOVQNZJYSORNB-UHFFFAOYSA-N 0.000 description 3
- 238000011161 development Methods 0.000 description 3
- 238000009472 formulation Methods 0.000 description 3
- 230000005484 gravity Effects 0.000 description 3
- 239000007791 liquid phase Substances 0.000 description 3
- 238000012986 modification Methods 0.000 description 3
- 230000004048 modification Effects 0.000 description 3
- 230000007547 defect Effects 0.000 description 2
- 238000011978 dissolution method Methods 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- BWGNESOTFCXPMA-UHFFFAOYSA-N Dihydrogen disulfide Chemical compound SS BWGNESOTFCXPMA-UHFFFAOYSA-N 0.000 description 1
- UCKMPCXJQFINFW-UHFFFAOYSA-N Sulphide Chemical compound [S-2] UCKMPCXJQFINFW-UHFFFAOYSA-N 0.000 description 1
- 230000005856 abnormality Effects 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 230000005540 biological transmission Effects 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- QGJOPFRUJISHPQ-NJFSPNSNSA-N carbon disulfide-14c Chemical compound S=[14C]=S QGJOPFRUJISHPQ-NJFSPNSNSA-N 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 230000001186 cumulative effect Effects 0.000 description 1
- 239000002360 explosive Substances 0.000 description 1
- 238000005429 filling process Methods 0.000 description 1
- 230000004907 flux Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
- E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting, e.g. eliminating, the deposition of paraffins or like substances
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
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- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Geochemistry & Mineralogy (AREA)
- Geophysics (AREA)
- Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Treating Waste Gases (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Gas Separation By Absorption (AREA)
Abstract
The invention discloses a sulfur deposition treatment method for a shaft of an ultra-deep sulfur-containing gas well, which comprises the steps of injecting sulfur solvent into the shaft in a small-displacement mode to a sulfur deposition formation position, closing the shaft for more than 2 days, opening the shaft after a wellhead is pressurized, performing large-yield flowback, and collecting residual liquid of the sulfur solvent after reaction, so that the treatment of sulfur deposition can be achieved; the beneficial effects of the invention are as follows: the method comprises the steps of taking an intersection point of a shaft pressure-temperature curve measured by a steel wire downward pressure gauge and a gas well elemental sulfur precipitation and solidification phase diagram as a shaft sulfur deposition position, taking the upper shaft volume of the sulfur deposition position as the filling amount of sulfur solvent, filling by an oil pipe in a small discharge amount, closing the shaft after pumping, and then discharging by large discharge amount gas to carry residual liquid of the pumped sulfur solvent; the sulfur deposition of the ultra-deep gas well is efficiently removed by a low-discharge, long-soaking and large-flowback treatment process through sulfur deposition position calculation.
Description
Technical Field
The invention relates to the field of exploitation of oil and gas fields, in particular to a method for treating sulfur deposition in a shaft of an ultra-deep sulfur-containing gas well.
Background
The depth of the ultra-deep sulfur-containing gas well is more than or equal to 5000 meters, for the depth of the gas well shaft reaching 6000-7000 m, the content of hydrogen sulfide reaches more than 5%, the ultra-deep sulfur-containing gas well has the characteristic of ultra-deep high sulfur content, the pressure of the current part of the gas well shaft is reduced to below 20MPa, the temperature is reduced to below 30 ℃, the production later period of the ultra-deep sulfur-containing gas well, the pressure, the temperature and the yield are reduced, simple substance sulfur in acid gas is easy to separate out and adhere to the shaft to form blocking throttle, the gas release of the gas well is influenced, and the sulfur deposition of the shaft is required to be melted or dissolved in real time by a physical or chemical method, so that the purposes of cleaning the shaft and smoothly delivering gas are achieved; and the output of the gas well is recovered to the positive output gas transmission capacity.
The existing method for treating sulfur deposition in a gas well shaft mainly comprises three categories of solvent dissolution, heating melting and chemical oxidation, but each has corresponding defect limitation, and cannot be conveniently and efficiently applied to ultra-deep sulfur-containing gas wells.
(1) The solvent dissolving method mainly uses solvents such as benzene, carbon disulfide, sulfide, dialkyl disulfide and the like, and adopts the filling processes such as well bore capillary filling, annular filling and the like to reach the bottom of the well, and then is carried along with the gas flow of the well to the ground along the well bore, so as to achieve the purpose of dissolving the sulfur deposition in the well bore.
(2) The heating and melting method is to pump circulating high-temperature steam through the annular space of a gas well or to fill circulating high-temperature steam or hot flux into a shaft by using a continuous oil pipe so as to achieve the purpose of high-temperature melting solid-phase sulfur deposition.
(3) The chemical oxidation method uses air to contact with sulfur deposition to achieve the purpose of chemical oxidation sulfur deposition.
There are problems: in the solvent dissolution method, sulfur solvent is filled into a capillary or an annulus, so that the solvent dissolution method is mainly suitable for a well shaft (the depth is less than 5000 m) of a gas well with a shallow shaft depth, has the problems of high cost, frequent abnormality, easy blockage of filling holes and the like, and is not suitable for sulfur deposition treatment of the well shaft of an ultra-deep sulfur-containing gas well;
In the heating and melting method, annulus heating is suitable for shallow wells, and the failure of an oil pipe at the bottom of the annulus and an annular space sealing packer is easy to occur; the continuous oil pipe filling method for the shaft has high cost, and the construction operation risk of the sulfur-containing gas well is high, so that the method is not suitable for the ultra-deep sulfur-containing gas well;
in chemical oxidation processes, air is not suitable for use in flammable and explosive sulfur-containing gas well bores.
Disclosure of Invention
The invention aims to overcome the defects of high sulfur deposition cost, high construction operation risk and the like in the prior art of solvent dissolution or heating melting treatment of an ultra-deep sulfur-containing gas well, and provides a method for treating the sulfur deposition of the shaft of the ultra-deep sulfur-containing gas well, so as to achieve the purpose of effectively removing the sulfur deposition of the ultra-deep gas well with low cost.
The aim of the invention is realized by the following technical scheme:
A sulfur deposition treatment method for ultra-deep sulfur-containing gas well shaft includes such steps as injecting sulfur solvent into shaft, closing well until the sulfur solvent flows down along the wall of shaft, vaporizing, pressurizing, opening well, and collecting residual liquid of sulfur solvent.
Aiming at the problem of sulfur deposition of an ultra-deep sulfur-containing gas well, a high-efficiency and rapid treatment method is provided, sulfur solvent is injected into the gas well from a sulfur deposition position to a wellhead position by precisely determining the sulfur deposition position, the sulfur solvent is fully flowed and vaporized along a well wall by closing the well, the contact time of liquid and solid-phase elemental sulfur is increased, the liquid and solid-phase elemental sulfur are fully dissolved and reacted, the vaporization effect is generated by utilizing the temperature of the ultra-deep gas well, the liquid column pressure of a shaft is reduced, the flowback of residual liquid is realized, and the treatment of sulfur deposition is further realized. The method has remarkable treatment effect on sulfur deposition with the well depth of more than 5000 meters, and has the advantage of low overall treatment cost.
Preferably, in order to further achieve the purpose of low cost and high efficiency, the sulfur deposition treatment method specifically comprises the following steps:
the sulfur deposition treatment method specifically comprises the following steps:
S1, determining a sulfur deposition position: determining the pressure and temperature of a sulfur deposition position formed by a gas well shaft according to a shaft pressure-temperature curve and the intersection point position of a solidification line of a gas well elemental sulfur phase diagram, wherein the corresponding shaft depth is the sulfur deposition position;
S2, determining the dosage of the sulfur solvent: calculating the dosage of the sulfur solvent according to the sulfur deposition position determined in the step S1, wherein the dosage of the sulfur solvent is the upper shaft volume of the sulfur deposition forming position in the gas well shaft, and determining the addition volume of the sulfur solvent through a shaft volume calculation formula;
s3, adding sulfur solvent: sulfur solvent is injected into the shaft according to the displacement of not higher than 0.2m 3/min, so that the liquid flows downwards along the wall surface mode, and the height of the liquid column in the shaft is reduced;
S4, closing the well: when the sulfur solvent is injected into a shaft, the liquid column pressure of the sulfur solvent is formed, so that the later residual liquid is difficult to flow back, the well is closed for more than 2 days, and under the action of gravity, the liquid column flows downwards along the wall surface of the shaft, so that on one hand, the high temperature of the shaft is utilized to accelerate the dissolution of elemental sulfur by the sulfur solvent, on the other hand, the liquid column pressure is reduced, and the later wellhead is convenient to lift;
S5, open well and reverse drainage: and after the well is closed, taking the gas flow rate of reasonable production allocation as a reference object, adjusting the gas flow rate, quickly returning and collecting residual liquid of the sulfur solvent.
The dimethyl disulfide is taken as a main body, and a catalyst, a hydrate inhibitor and a corrosion inhibitor are matched to determine a specific formula of the sulfur solvent; the sulfur deposition site is determined by using the intersection point of the shaft pressure-temperature curve and the gas well elemental sulfur phase diagram as the shaft sulfur deposition site, compared with a thermodynamic calculation method, the sulfur deposition site is obtained by using the intersection point of the elemental sulfur phase diagram plate obtained through experiments and the real-time shaft pressure-temperature curve, the method is simpler and more convenient, and the data source experiment and the on-site measured data are based, so that the sulfur deposition site is more accurate and stable than a calculation formula. And then filling the upper shaft volume of the sulfur deposition position serving as the addition amount of the sulfur solvent in a small-displacement mode, closing the well for a period of time, enabling the sulfur solvent to flow and vaporize fully, enabling a wellhead to be pressurized, and then discharging gas in stages, so that the sulfur solvent liquid after dissolving sulfur deposition can be discharged out of the shaft rapidly under the action of flowing gas, thereby achieving the purposes of low cost and high efficiency.
Preferably, for the purpose of further low cost, the wellbore pressure-temperature curve is obtained by real-time combined measurement of the pressure of the steel wire under the wellbore and the thermometer. The gas pressure in the shaft is accurately measured by using simple steel wire pressure, namely, the steel wire with the pressure gauge is lowered to different depths of the shaft to realize the measurement of the gas pressure; and the thermometer measures the real-time temperature in the shaft, so that the data of the pressure-temperature curve is measured by a simple measuring method, and the aim of low cost is fulfilled.
Preferably, in order to further realize the purpose of removing sulfur deposition of the ultra-deep gas well with low cost and high efficiency, a filling pump is used for filling sulfur solvent into the gas well shaft, and the filling pump is used for replacing the filling pump for filling the annular space or the capillary tube for filling the oil pipe, so that the small-displacement filling is performed.
Preferably, in step S5, the adjustment of the gas flow includes a first stage and a second stage, where the first stage sets the gas flow to 1.5-2 times of the reasonably produced gas flow, and the second stage adjusts the gas flow to the reasonably produced gas flow, and the condition for entering the second stage is that the wellhead pressure is recovered and stabilized. The gas flow at the initial stage of liquid discharge is set to be 1.5 times of the gas flow at the reasonable production allocation by taking the gas flow at the reasonable production allocation as a reference, so that the discharge of the residual liquid of the sulfur solvent is quickened, and the aim of efficiently removing sulfur deposition of an ultra-deep gas well is fulfilled.
Preferably, for the purpose of further realizing low-cost removal of sulfur deposits in ultra-deep gas wells, the volume formula of the injected sulfur solvent is as follows:
V＝π*r2*H
Wherein the H-sulfur deposition location corresponds to wellbore depth in units of: m;
r-wellbore inner radius, unit: m;
Pi-circumference ratio coefficient;
V-Sulfur solvent usage, units: m 3; the upper cylinder volume of the sulfur deposition position is used as the addition amount of the sulfur solvent, so that the sulfur solvent is accurately added, the cost is reduced, and the purpose of removing the sulfur deposition of the ultra-deep gas well with low cost is realized.
Preferably, in order to further realize the purpose of efficiently removing sulfur deposition of an ultra-deep gas well, the sulfur solvent is required to flow rapidly along the well wall under the self gravity, the flow rate can reach 1000 meters per two hours, and the vaporization effect occurs at 50-100 ℃ and above.
Wherein, the vaporization effect refers to: at high temperature and large surface area, the liquid molecules absorb little heat of vaporization (latent heat of vaporization), overcome intermolecular attraction, increase the molecular spacing, become gas molecules, i.e. the liquid is more easily vaporized into gas at high temperature and large surface area, and reduce the liquid column pressure of the well bore.
The sulfur solvent is a mixture aqueous solution of dimethyl disulfide, polyalkylene hydroxylamine, ethylene glycol and WD 11; the sulfur solvent formula comprises 10-20% of dimethyl disulfide, 2-5% of polyalkylene hydroxylamine, 5-15% of ethylene glycol and 1-5% of WD11, wherein WD11 is taken as a corrosion inhibitor, so that corrosion of materials can be prevented or slowed down, and the balance is water;
further, the specific formula of the sulfur solvent is an aqueous solution of a mixture of 15% of dimethyl disulfide, 3% of polyalkylene hydroxylamine, 10% of ethylene glycol and 2% of WD11 in percentage by mass; the dimethyl disulfide is used as a purifying solvent, the polyalkylene hydroxylamine is used as a catalyst to catalyze the sulfur solvent to react with sulfur deposition, the ethylene glycol is used as a hydrate inhibitor to prevent water in the sulfur solvent from forming a hydrate, and WD11 is used as a corrosion inhibitor to prevent a pipeline from being corroded in a sulfur deposition dissolution stage, so that the purpose of efficiently removing sulfur deposition of an ultra-deep gas well is realized.
The beneficial effects of the invention are as follows:
1. The intersection point of the shaft pressure-temperature curve and the elemental sulfur solidification line in the gas well elemental sulfur phase diagram is used as a shaft sulfur deposition position, compared with a thermodynamic calculation method, a sulfur deposition position is determined, the obtained result is more accurate, then the upper shaft volume of the sulfur deposition position is used as the addition amount of sulfur solvent, the filling is carried out in a small-displacement mode, meanwhile, the well is closed for a period of time, the sulfur solvent is fully dissolved, the wellhead is promoted to be pressurized, and then gas is discharged in stages, so that the sulfur solvent liquid after dissolved sulfur deposition can be rapidly discharged out of the shaft under the action of pressure, and the purposes of low cost and high efficiency are realized.
2. The pressure gauge is lowered by a simple steel wire, the pressure in the shaft is accurately measured, and the real-time temperature in the shaft is measured by the thermometer, so that the data of the pressure-temperature curve is measured by a simple measuring method, and the purpose of true and reliable data is realized.
3. The oil pipe is used for filling with small displacement, compared with annular pumping and capillary pumping, the pumping mode is safer, the operation is simple, the operation cost is low, the long-time well closing and closing mode is matched, the sulfur solvent can be promoted to flow and vaporize fully along the well wall, the contact time of liquid and solid-phase elemental sulfur is increased, the reaction is fully dissolved, the liquid column pressure of a shaft can be reduced, the flowback of residual liquid is facilitated, and the purpose of removing sulfur deposition of an ultra-deep gas well with low cost and high efficiency is achieved.
4. By taking the gas flow of reasonable production allocation as a reference, the gas flow of the initial stage of liquid discharge is set to be 1.5-2.0 times of the gas flow of reasonable production allocation, so that the discharge of residual liquid of the sulfur solvent is accelerated, the rapid discharge of sulfur deposition after dissolution is accelerated, and the purpose of efficiently removing the sulfur deposition of an ultra-deep gas well is realized.
5. The upper cylinder volume of the sulfur deposition position is used as the addition amount of the sulfur solvent, so that the sulfur solvent is accurately added, the cost is reduced, and the purpose of removing the sulfur deposition of the ultra-deep gas well with low cost is realized.
6. The dimethyl disulfide is used as a purifying solvent, the polyalkylene hydroxylamine is used as a catalyst to catalyze the dissolution of sulfur deposition, the ethylene glycol is used as a hydrate inhibitor to prevent water in the sulfur solvent from forming a hydrate, and WD11 is used as a corrosion inhibitor to prevent a pipeline from being corroded in the stage of sulfur deposition dissolution, so that the purpose of efficiently removing the sulfur deposition of an ultra-deep gas well is realized.
Drawings
FIG. 1 is a schematic illustration of the sulfur deposit formation location determination of the present invention.
Detailed Description
The technical solution of the present invention will be described in further detail with reference to the accompanying drawings, but the scope of the present invention is not limited to the following description.
The gas well in a certain area is taken as a research object, the depth of the well bore reaches 6000-7000 m, the content of hydrogen sulfide reaches more than 5%, the ultra-deep high sulfur-containing characteristic is realized, the pressure of the well bore of a part of the gas well is reduced to below 20MPa, the temperature is reduced to below 30 ℃, sulfur deposition is easy to occur in the well bore, the well bore of the gas well is blocked, and the gas release is influenced.
Example 1
Sulfur deposition abatement for well # 1
A sulfur deposition treatment method for a shaft of an ultra-deep sulfur-containing gas well, wherein the shaft depth of a No.1 gas well is 6800 m, and the gas release capacity caused by sulfur deposition is reduced from 40 trillion per day to 20 trillion per day and continuously reduced;
A pressure gauge and a thermometer are put into a shaft through a steel wire, a shaft pressure-temperature curve is determined, an elemental sulfur phase diagram of a gas well is utilized to determine an elemental sulfur solidification line, the intersection point position of the shaft pressure-temperature curve and the elemental sulfur solidification line is the pressure and the temperature of a sulfur deposition position formed by the shaft of the gas well, the depth of the corresponding shaft is 5000 meters, and the sulfur deposition position is shown in figure 1;
Calculating the sulfur solvent dosage according to the sulfur deposition position in the previous step, wherein the sulfur solvent dosage is the upper shaft volume of the sulfur deposition forming position in the gas well shaft, and determining the addition volume of the sulfur solvent through a shaft volume calculation formula; the calculated upper wellbore volume from the sulfur deposit formation site was 22.5 square, i.e., the addition volume of sulfur solvent was 22.5 square;
Injecting sulfur solvent into a shaft at a displacement of 0.15m 3/min to a sulfur deposition forming position, closing the shaft for 3 days, raising the pressure of the shaft mouth to 15MPa, opening the shaft for large-yield flowback, setting the production allocation of a No. 1 shaft to 40 square/day, setting the gas flow to 60 square/day in the first stage, namely in the initial stage of opening the shaft for draining liquid, waiting until the oil pressure of the shaft mouth is completely restored to 20MPa, and regulating the gas flow to the gas flow of 40 square/day after the oil pressure of the shaft mouth is kept stable; in this example, the sulfur solvent formulated by the overall formulation itself was an aqueous mixture of dimethyl disulfide, polyalkylene hydroxylamine, ethylene glycol, and WD11 (supplied by Suiss, france); the specific formula of the sulfur solvent is an aqueous solution of a mixture of 15% of dimethyl disulfide, 3% of polyalkylene hydroxylamine, 10% of ethylene glycol and 2% of WD11 in percentage by mass; the dimethyl disulfide is used as a purifying solvent, the polyalkylene hydroxylamine is used as a catalyst to catalyze the dissolution of sulfur deposition, the ethylene glycol is used as a hydrate inhibitor to prevent water in the sulfur solvent from forming a hydrate, and WD11 is used as a corrosion inhibitor to prevent a pipeline from being corroded in the stage of sulfur deposition dissolution, so that the purpose of efficiently removing the sulfur deposition of an ultra-deep gas well is realized.
In this embodiment, only one component formulation of a specific sulfur solvent is adopted, and in the sulfur deposition treatment process, the sulfur solvent used only has vaporization effect under the gravity of the sulfur solvent and at a temperature not lower than 50 ℃, and can flow rapidly along the well wall and dissolve sulfur, so that the sulfur solvent is not limited to one component formulation of the sulfur solvent.
After sulfur deposition treatment is carried out by the method of the embodiment, the yield of the No.1 well is restored to 40 ten thousand square/day, the construction operation cost is only 10 ten thousand yuan, and no hydrogen sulfide leakage occurs.
Example 2
Sulfur deposition abatement for 2# well
A sulfur deposition treatment method for a well shaft of an ultra-deep sulfur-containing gas well, wherein the well shaft of a No.2 gas well is 6850 m deep, and the gas release capacity caused by sulfur deposition is reduced from 40 trillion per day to 20 trillion per day and continuously reduced;
A pressure gauge and a thermometer are arranged in a shaft through a steel wire, a shaft pressure-temperature curve is determined, an elemental sulfur solidification line is determined by utilizing a gas well elemental sulfur phase diagram, the intersection point position of the shaft pressure-temperature curve and the elemental sulfur solidification line is the pressure and the temperature of a sulfur deposition position formed by the gas well shaft, and the depth of the corresponding shaft is 4500 m;
Calculating the sulfur solvent dosage according to the sulfur deposition position in the previous step, wherein the sulfur solvent dosage is the upper shaft volume of the sulfur deposition forming position in the gas well shaft, and determining the addition volume of the sulfur solvent through a shaft volume calculation formula; the calculated upper wellbore volume from the sulfur deposit formation site was 20.25 square, i.e., the addition volume of sulfur solvent was 20.25 square;
Injecting sulfur solvent into a shaft at a displacement of 0.2m 3/min to a sulfur deposition forming position, closing the shaft for 3 days, raising the pressure of the shaft mouth to 16MPa, opening the shaft for large-yield flowback, setting the production allocation of a No. 2 shaft to 40 square/day, setting the gas flow to 70 square/day in the first stage, namely in the initial stage of opening the shaft for draining liquid, waiting until the oil pressure of the shaft mouth is completely restored to 22MPa, and regulating the gas flow to the gas flow of 40 square/day after the oil pressure of the shaft mouth is kept stable; in this example, the sulfur solvent used was identical to well # 1.
After sulfur deposition treatment is carried out by the method of the embodiment, the production allocation of the No. 2 well is restored to 40 ten thousand square/day, the construction operation cost is only 10 ten thousand yuan, and no hydrogen sulfide leakage occurs.
Example 3
Sulfur deposition abatement for 3# well
A sulfur deposition treatment method for a well shaft of an ultra-deep sulfur-containing gas well, wherein the well shaft of a 3# gas well is 6500 meters deep, and the gas release capacity caused by sulfur deposition is reduced from 20 to 5 trillion per day and continuously reduced;
a pressure gauge and a thermometer are arranged in a shaft through a steel wire, a shaft pressure-temperature curve is determined, an elemental sulfur solidification line is determined by utilizing a gas well elemental sulfur phase diagram, the intersection point position of the shaft pressure-temperature curve and the elemental sulfur solidification line is the pressure and the temperature of a sulfur deposition position formed by the gas well shaft, and the corresponding shaft depth is 5200 meters;
Calculating the sulfur solvent dosage according to the sulfur deposition position in the previous step, wherein the sulfur solvent dosage is the upper shaft volume of the sulfur deposition forming position in the gas well shaft, and determining the addition volume of the sulfur solvent through a shaft volume calculation formula; the calculated upper wellbore volume from the sulfur deposit formation site was 23.4 square, i.e., the addition volume of sulfur solvent was 23.4 square;
Injecting sulfur solvent into a shaft at a displacement of 0.1m 3/min to a sulfur deposition forming position, closing the shaft for 5 days, raising the pressure of the shaft mouth to 8MPa, opening the shaft for large-yield flowback, setting the production allocation of a 3# shaft to 20 square/day, setting the gas flow to 40 square/day in the first stage, namely in the initial stage of opening the shaft for draining, waiting until the oil pressure of the shaft mouth is completely restored to 12MPa, and regulating the gas flow to 20 square/day after the oil pressure is kept stable; in this example, the sulfur solvent used was identical to well # 1.
After sulfur deposition treatment is carried out by the method of the embodiment, the production allocation of the 3# well is restored to 20 ten thousand square/day, the construction operation cost is only 10 ten thousand yuan, and no hydrogen sulfide leakage occurs.
Comparative example 1
Sulfur deposition abatement for well # 4
A sulfur deposition treatment method for a well shaft of an ultra-deep sulfur-containing gas well, wherein the well shaft of a No. 4 gas well is 6800 m deep, and the gas release capacity caused by sulfur deposition is reduced from 40 trillion per day to 10 trillion per day and continuously reduced;
a pressure gauge and a thermometer are arranged in a shaft through a steel wire, a shaft pressure-temperature curve is determined, an elemental sulfur solidification line is determined by utilizing a gas well elemental sulfur phase diagram, the intersection point position of the shaft pressure-temperature curve and the elemental sulfur solidification line is the pressure and the temperature of a sulfur deposition position formed by the gas well shaft, and the depth of the corresponding shaft is 5000 meters;
Calculating the sulfur solvent dosage according to the sulfur deposition position in the previous step, wherein the sulfur solvent dosage is the upper shaft volume of the sulfur deposition forming position in the gas well shaft, and determining the addition volume of the sulfur solvent through a shaft volume calculation formula; the calculated upper wellbore volume from the sulfur deposit formation site was 22.5 square, i.e., the addition volume of sulfur solvent was 22.5 square;
Injecting sulfur solvent into a shaft at a displacement of 0.5m 3/min to a sulfur deposition forming position, closing the shaft for 3 days, raising the pressure of the shaft to 2MPa, and as the oil pressure of the shaft is lower, the shaft cannot be opened at a large displacement, the residual liquid is returned in a large yield, and in the first stage, namely in the initial stage of opening the shaft and draining, the maximum displacement of the gas well is only 5 trillion per day until the oil pressure of the shaft is completely restored to 10MPa, and after the oil pressure is kept stable, raising the maximum flow of gas to only 10 trillion per day, continuously lowering the oil pressure, and ensuring poor treatment effect; in this example, the sulfur solvent used in this comparative example was the same as that used in example 1 to treat # 1 well.
After sulfur deposition treatment is carried out by the method of the comparative example, the production allocation of the No. 4 well is restored to 10 square/day, the production allocation is continuously reduced, the construction operation cost is 10 ten thousand yuan, and no hydrogen sulfide leakage occurs.
Comparative example 2
Sulfur deposition abatement for well # 5
A sulfur deposition treatment method for a shaft of an ultra-deep sulfur-containing gas well, wherein the shaft depth of a 5# gas well is 6800 m, and the gas release capacity caused by sulfur deposition is reduced from 40 trillion per day to 20 trillion per day and continuously reduced;
a pressure gauge and a thermometer are arranged in a shaft through a steel wire, a shaft pressure-temperature curve is determined, an elemental sulfur solidification line is determined by utilizing a gas well elemental sulfur phase diagram, the intersection point position of the shaft pressure-temperature curve and the elemental sulfur solidification line is the pressure and the temperature of a sulfur deposition position formed by the gas well shaft, and the depth of the corresponding shaft is 5000 meters;
Calculating the sulfur solvent dosage according to the sulfur deposition position in the previous step, wherein the sulfur solvent dosage is the upper shaft volume of the sulfur deposition forming position in the gas well shaft, and determining the addition volume of the sulfur solvent through a shaft volume calculation formula; the calculated upper wellbore volume from the sulfur deposit formation site was 22.5 square, i.e., the addition volume of sulfur solvent was 22.5 square;
Injecting sulfur solvent into a shaft at a displacement of 0.15m 3/min to a sulfur deposition formation position, closing the shaft for half a day, raising the pressure of the shaft to 1MPa, and as the oil pressure of the shaft is lower, the shaft cannot be opened at a large displacement, the residual liquid is returned in a large yield, and in the first stage, namely in the initial stage of the liquid discharge, the maximum displacement of the shaft is only 5 trillion per day, until the oil pressure of the shaft is completely restored to 15MPa, and after the oil pressure is kept stable, raising the maximum flow of gas to only 20 trillion per day, continuously lowering, and ensuring poor treatment effect; in this example, the sulfur solvent used in this comparative example was the same as that used in example 1 to treat # 1 well.
After sulfur deposition treatment is carried out by the method of the comparative example, the production allocation of the No. 5 well is restored to 20 square/day, the production allocation is continuously reduced, the construction operation cost is 10 ten thousand yuan, and no hydrogen sulfide leakage occurs.
Comparative example 3
Sulfur deposition abatement for 6# well
A sulfur deposition treatment method for a shaft of an ultra-deep sulfur-containing gas well, wherein the shaft of a No. 5 gas well is 7000 m deep, and the gas release capacity caused by sulfur deposition is reduced from 40 to 10 trillion per day and continuously reduced;
determining a shaft pressure-temperature curve by a steel wire downward pressure gauge and a thermometer into a shaft, determining an elemental sulfur solidification line by using a gas well elemental sulfur phase diagram, wherein the intersection point position of the shaft pressure-temperature curve and the elemental sulfur solidification line is the pressure and the temperature of a sulfur deposition position formed by the gas well shaft, the depth of the corresponding shaft is 5000 meters, the calculated upper shaft volume from the sulfur deposition position is 22.5 square, namely the addition volume of sulfur solvent is 22.5 square;
Injecting sulfur solvent into a shaft through a coiled tubing at a discharge capacity of 0.15m 3/min by adopting the coiled tubing to a position of 5000 meters in the shaft, closing the shaft for 3 days, raising the pressure of the shaft mouth to 16MPa, opening the shaft for large-yield flowback, setting the yield of a 6# shaft to 40 square/day, setting the gas flow to 60 square/day in the first stage, namely the initial stage of opening the shaft for discharging liquid, waiting until the oil pressure of the shaft mouth is completely restored to 20MPa, and regulating the gas flow to 40 square/day after keeping stable; the sulfur solvent used in this comparative example was the same as that used in example 1 for treating well # 1.
After sulfur deposition treatment by the method of the comparative example, the production allocation of the 6# well is restored to 40 ten thousand square/day, the construction operation cost reaches 100 ten thousand yuan, and hydrogen sulfide leakage occurs.
Comparative example 4
Sulfur deposition abatement for 7# well
The 7# gas well wellbore was 7000 meters deep, and the gas release capacity due to sulfur deposition was reduced from 40 to 10 square/day and continued to decrease;
Determining a sulfur deposition position by adopting a thermodynamic calculation method based on temperature data and gas flow data, wherein the position corresponding to 4000 meters of shaft depth is a sulfur deposition formation position; determining a sulfur deposition position by adopting a shaft pressure-temperature curve and a solidification line in a gas well elemental sulfur phase diagram, wherein the depth of a shaft corresponding to 5000 meters is a sulfur deposition forming position, and the adding volume of a sulfur solvent is 4000 meters, namely 18 square;
Injecting sulfur solvent into a shaft at a displacement of 0.15m 3/min to a sulfur deposition forming position, closing the shaft for 3 days, raising the pressure of the shaft to 15MPa, opening the shaft for large-yield flowback, setting the yield of the 7# shaft to 40 square/day, setting the gas flow to 60 square/day in the first stage, namely the initial stage of opening the shaft for draining, waiting until the oil pressure of the shaft is completely restored to 20MPa, and regulating the gas flow to 40 square/day after the oil pressure of the shaft is kept stable; the sulfur solvent used in this comparative example was the same as that used in example 1 for treating well # 1.
After sulfur deposition treatment by the method of this comparative example, the production of the 7# well was restored to 40 square/day, but continued to decrease, the construction cost was 10 ten thousand yuan, and no leakage of hydrogen sulfide occurred.
Comparative example 5
Sulfur deposition abatement for 8# well
The 8# gas well has a well bore depth of 6800 meters, and the gas release capacity due to sulfur deposition is reduced from 40 to 20 square/day and continues to be reduced;
Determining a sulfur deposition position by adopting a shaft pressure-temperature curve and a solidification line in a gas well elemental sulfur phase diagram, wherein the shaft depth corresponding to 5000 meters is a sulfur deposition forming position, namely 22.5 square;
injecting sulfur solvent into a shaft at a displacement of 0.15m 3/min to a sulfur deposition forming position, closing the shaft for 3 days, raising the pressure of the shaft mouth to 15MPa, opening a large-yield flowback, and allocating the production of an 8# shaft to 40 square/day, wherein shaft drainage is not carried out in stages, namely the production of the gas well is maintained at 40 square/day, and the pressure of the shaft mouth is restored to 20MPa; the sulfur solvent used in this comparative example was the same as that used in example 1 for treating well # 1.
After sulfur deposit control by the method of this comparative example, 8# well production was restored to 40 square/day, but well bore sulfur deposits were not completely discharged, there was a choked flow, and production continued to drop. The construction cost is 10 ten thousand yuan, and no leakage of hydrogen sulfide occurs.
Table 1 is obtained by counting the cumulative recovered gas flow, construction operation costs, and hydrogen sulfide leakage over 30 days in comparative examples 1 to 3 and comparative examples 1 to 5.
Table 1 comparative tables of examples 1-3 and comparative examples 1-5
As can be seen from table 1, when the sulfur deposition position is determined by a wellbore pressure-temperature curve and a gas well elemental sulfur phase diagram and referring to a saturated elemental sulfur precipitation curve, and an aqueous solution of a mixture of 15% dimethyl disulfide, 3% polyalkylene hydroxylamine, 10% ethylene glycol and 2% WD11 is used as a sulfur solvent, and the sulfur deposition wellbore is treated by a "small-displacement, long-soaking, large-flowback" oil pipe pumping method, the gas yield is obviously recovered, the cost is low, and no leakage of hydrogen sulfide occurs; when the high-displacement short-time soaking is adopted, the formula and the dosage are the same, but the wellhead pressurizing pressure is smaller, so that the dissolution effect of the integral sulfur deposition is affected; when the coiled tubing is adopted to pump the well bore, the formula, the dosage and the well closing time are the same, but the operation cost is high, and the leakage of hydrogen sulfide occurs; when the sulfur deposition position of the shaft is calculated by thermodynamics, the corresponding sulfur solvent consumption is obtained, the formula, pumping discharge capacity and well closing soaking time are the same, but the normal production allocation cannot be recovered, and the treatment effect is poor.
In conclusion, under the background that the development of the gas field at home and abroad generally tends to the development of the ultra-deep sulfur-containing gas well (accounting for 40 percent of natural gas reserves at home and abroad), the middle and later stages of the development of the gas field face the difficult problem of sulfur deposition and blockage of the gas well shaft, so that the invention can be effectively applied to sulfur deposition treatment of the ultra-deep sulfur-containing gas well shaft.
The foregoing is merely a preferred embodiment of the invention, and it is to be understood that the invention is not limited to the form disclosed herein but is not to be construed as excluding other embodiments, but is capable of numerous other combinations, modifications and environments and is capable of modifications within the scope of the inventive concept, either as taught or as a matter of routine skill or knowledge in the relevant art. And that modifications and variations which do not depart from the spirit and scope of the invention are intended to be within the scope of the appended claims.
Claims (8)
1. A sulfur deposition treatment method for a sulfur-containing gas well shaft is characterized by comprising the following steps of: injecting sulfur solvent into the shaft to a sulfur deposition forming position, closing the shaft for at least two days, waiting for the pressure rising at the well head, and opening the shaft for staged flowback to realize sulfur deposition treatment;
the sulfur deposition treatment method specifically comprises the following steps:
S1, determining a sulfur deposition position: determining the pressure and temperature of a sulfur deposition position formed by a gas well shaft according to the intersection point position of a shaft pressure-temperature curve and a solidification line of an elemental sulfur phase diagram, wherein the corresponding well depth is the sulfur deposition position;
S2, determining the dosage of the sulfur solvent: calculating the dosage of the sulfur solvent according to the sulfur deposition position determined in the step S1, wherein the dosage of the sulfur solvent is the upper well volume of the sulfur deposition forming position in the well shaft of the gas well, and determining the addition volume of the sulfur solvent through a well shaft volume calculation formula;
S3, adding sulfur solvent: injecting sulfur solvent into the well bore according to the displacement of not higher than 0.2m 3/min;
s4, closing the well: when the sulfur solvent is injected into the shaft, forming the liquid column pressure of the sulfur solvent, wherein the liquid column pressure is higher than the highest shut-in oil pressure of a wellhead of the gas well, closing the shaft, enabling the sulfur solvent to flow downwards along the wall surface of the shaft and be vaporized under the action of temperature, and reducing the liquid column pressure until the wellhead is pressurized;
S5, open well and reverse drainage: and after the well is closed, taking the gas flow rate of reasonable production allocation as a reference object, adjusting the gas flow rate, and carrying out flowback and collecting residual liquid of the sulfur solvent.
2. The method for treating sulfur deposition in a sulfur-containing gas well shaft according to claim 1, wherein the method comprises the following steps: the pressure-temperature curve of the shaft is obtained by real-time combined measurement of the pressure of the steel wire which is put into the shaft and a thermometer.
3. The method for treating sulfur deposition in a sulfur-containing gas well shaft according to claim 1, wherein the method comprises the following steps: and directly injecting sulfur solvent into the shaft by adopting an injection pump.
4. A sulfur deposition abatement method for a sulfur-containing gas well wellbore according to claim 3, wherein: in step S5, the adjustment of the gas flow includes a first stage and a second stage, where the first stage sets the gas flow to 1.5-2 times of the reasonably produced gas flow, and the second stage adjusts the gas flow to the reasonably produced gas flow, and the condition for entering the second stage is that the wellhead oil pressure is recovered and stabilized.
5. The method for treating sulfur deposition in a sulfur-containing gas well shaft according to claim 1, wherein the method comprises the following steps: the volume formula of the gas well shaft is as follows:
V=π*r²*H
Wherein, the H-sulfur deposition position corresponds to the depth of a shaft, and the unit is m;
r-wellbore inner radius, unit: m;
Pi-circumference ratio coefficient;
V-Sulfur solvent is used in m 3.
6. The method for treating sulfur deposition in a sulfur-containing gas well shaft according to claim 1, wherein the method comprises the following steps: the sulfur solvent is required to have a vaporization effect under its own weight at a temperature of not less than 50 ℃ and to be capable of rapid flow along the well wall.
7. The sulfur deposition abatement method for a sulfur-containing gas well wellbore of claim 6, wherein: the sulfur solvent is a mixture aqueous solution containing dimethyl disulfide, polyalkylene hydroxylamine, ethylene glycol and WD 11.
8. The sulfur deposition abatement method for a sulfur-containing gas well bore of claim 7, wherein: the sulfur solvent is prepared from the following raw materials in percentage by mass: 10-20% of dimethyl disulfide, 2-5% of polyalkylene hydroxylamine, 5-15% of ethylene glycol, 1-5% of WD11 and the balance of water.
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