CN114198060A - Ultra-deep sulfur-containing gas well shaft sulfur deposition treatment method - Google Patents
Ultra-deep sulfur-containing gas well shaft sulfur deposition treatment method Download PDFInfo
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- CN114198060A CN114198060A CN202010898699.3A CN202010898699A CN114198060A CN 114198060 A CN114198060 A CN 114198060A CN 202010898699 A CN202010898699 A CN 202010898699A CN 114198060 A CN114198060 A CN 114198060A
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- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 title claims abstract description 336
- 229910052717 sulfur Inorganic materials 0.000 title claims abstract description 305
- 239000011593 sulfur Substances 0.000 title claims abstract description 305
- 230000008021 deposition Effects 0.000 title claims abstract description 152
- 238000000034 method Methods 0.000 title claims abstract description 51
- 239000002904 solvent Substances 0.000 claims abstract description 120
- 239000007788 liquid Substances 0.000 claims abstract description 33
- 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 11
- 238000004364 calculation method Methods 0.000 claims abstract description 11
- 238000002347 injection Methods 0.000 claims abstract description 11
- 239000007924 injection Substances 0.000 claims abstract description 11
- 239000010959 steel Substances 0.000 claims abstract description 11
- 238000007599 discharging Methods 0.000 claims abstract description 6
- 238000006243 chemical reaction Methods 0.000 claims abstract description 5
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 claims description 31
- 238000004519 manufacturing process Methods 0.000 claims description 25
- WQOXQRCZOLPYPM-UHFFFAOYSA-N dimethyl disulfide Chemical compound CSSC WQOXQRCZOLPYPM-UHFFFAOYSA-N 0.000 claims description 24
- 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
- 238000009834 vaporization Methods 0.000 claims description 7
- 230000008016 vaporization Effects 0.000 claims description 7
- 239000000203 mixture Substances 0.000 claims description 6
- 230000005484 gravity Effects 0.000 claims description 4
- 238000005259 measurement Methods 0.000 claims description 4
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 3
- 239000002994 raw material Substances 0.000 claims 1
- 238000006073 displacement reaction Methods 0.000 abstract description 9
- 238000005086 pumping Methods 0.000 abstract description 4
- 238000002791 soaking Methods 0.000 abstract description 3
- 230000009286 beneficial effect Effects 0.000 abstract description 2
- 238000001556 precipitation Methods 0.000 abstract description 2
- 239000007789 gas Substances 0.000 description 144
- 208000028659 discharge Diseases 0.000 description 21
- 230000000052 comparative effect Effects 0.000 description 18
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 14
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 13
- 238000010276 construction Methods 0.000 description 11
- 239000003112 inhibitor Substances 0.000 description 9
- 238000004090 dissolution Methods 0.000 description 8
- 238000005067 remediation Methods 0.000 description 8
- 238000011049 filling Methods 0.000 description 7
- 230000015572 biosynthetic process Effects 0.000 description 6
- 230000007797 corrosion Effects 0.000 description 6
- 238000005260 corrosion Methods 0.000 description 6
- 230000008018 melting Effects 0.000 description 6
- 238000002844 melting Methods 0.000 description 6
- 239000000126 substance Substances 0.000 description 6
- 238000010438 heat treatment Methods 0.000 description 5
- 239000003054 catalyst Substances 0.000 description 4
- UHOVQNZJYSORNB-UHFFFAOYSA-N Benzene Chemical compound C1=CC=CC=C1 UHOVQNZJYSORNB-UHFFFAOYSA-N 0.000 description 3
- 239000005864 Sulphur Substances 0.000 description 3
- 238000011161 development Methods 0.000 description 3
- 230000003647 oxidation Effects 0.000 description 3
- 238000007254 oxidation reaction Methods 0.000 description 3
- 238000000746 purification Methods 0.000 description 3
- 239000007790 solid phase Substances 0.000 description 3
- 239000007864 aqueous solution Substances 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 230000007547 defect Effects 0.000 description 2
- WGCNASOHLSPBMP-UHFFFAOYSA-N hydroxyacetaldehyde Natural products OCC=O WGCNASOHLSPBMP-UHFFFAOYSA-N 0.000 description 2
- 239000007791 liquid phase Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 239000000243 solution Substances 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
- 230000005540 biological transmission Effects 0.000 description 1
- QGJOPFRUJISHPQ-NJFSPNSNSA-N carbon disulfide-14c Chemical compound S=[14C]=S QGJOPFRUJISHPQ-NJFSPNSNSA-N 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 230000001186 cumulative effect Effects 0.000 description 1
- TXKMVPPZCYKFAC-UHFFFAOYSA-N disulfur monoxide Inorganic materials O=S=S TXKMVPPZCYKFAC-UHFFFAOYSA-N 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 239000002360 explosive Substances 0.000 description 1
- 238000005429 filling process Methods 0.000 description 1
- 238000007654 immersion Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000000691 measurement method Methods 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
- XTQHKBHJIVJGKJ-UHFFFAOYSA-N sulfur monoxide Chemical compound S=O XTQHKBHJIVJGKJ-UHFFFAOYSA-N 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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, limiting or eliminating the deposition of paraffins or like substances
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
Abstract
The invention discloses a method for treating sulfur deposition in a shaft of an ultra-deep sulfur-containing gas well, which comprises the steps of injecting a sulfur solvent into the shaft in a small displacement mode until the sulfur deposition forming position, closing the shaft for more than 2 days, opening the shaft after the pressure of a well head rises, returning the well with large yield, and collecting the residual sulfur solvent after reaction, namely treating the sulfur deposition; the invention has the beneficial effects that: the method comprises the following steps of taking a shaft pressure-temperature curve measured by lowering a pressure gauge with a steel wire, taking the intersection point of the shaft pressure-temperature curve 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 injection dosage of a sulfur solvent, injecting with small displacement through an oil pipe, closing a well after pumping, then discharging with large displacement, and carrying pump injection sulfur solvent residual liquid; the sulfur deposition of the ultra-deep gas well is efficiently removed through the sulfur deposition position calculation, low-discharge, long-soaking and large-flowback treatment process.
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, the depth of a gas well shaft reaches 6000-7000 m, the content of hydrogen sulfide reaches more than 5%, and the ultra-deep sulfur-containing gas well has the characteristics of ultra-deep high sulfur content, the pressure of part of the gas well shaft is reduced to be below 20MPa, the temperature is reduced to be below 30 ℃, the pressure, the temperature and the yield are reduced in the later production stage of the ultra-deep sulfur-containing gas well, elemental sulfur in acid gas is easy to separate out and adhere to the shaft to form blockage throttling, the gas release of the gas well is influenced, and a physical or chemical method is needed to melt or dissolve the sulfur deposition of the shaft in real time, so that the purposes of cleaning the shaft and smoothly conveying the gas are achieved; and the gas well yield is recovered to the positive gas transmission capacity.
The existing gas well shaft sulfur deposition treatment methods mainly comprise three categories of solvent dissolution, heating melting and chemical oxidation, but have corresponding defects and cannot be conveniently and efficiently applied to an ultra-deep sulfur-containing gas well.
(1) The solvent dissolving method mainly comprises the steps of filling solvents such as benzene, carbon disulfide, sulfide, dialkyl disulfide and the like to the bottom of a gas well through filling processes such as wellbore capillary filling, annular space filling and the like, and then carrying the solvents along a wellbore to the ground along with gas flow of the gas well to achieve the purpose of dissolving wellbore sulfur deposition.
(2) The heating and melting method comprises the steps of pumping circulating high-temperature steam through the annulus of the gas well, or filling circulating high-temperature steam or a hot melting agent into a shaft by using a coiled tubing, so as to achieve the purpose of melting solid-phase sulfur deposition at high temperature.
(3) The chemical oxidation method uses air to contact with sulfur deposition to achieve the purpose of chemical sulfur oxide deposition.
There are problems: in the solvent dissolving method, the sulfur solvent is injected through a capillary or an annulus, so that the method is mainly suitable for a gas well shaft with shallow shaft depth (the depth is less than 5000m), has the problems of high cost, frequent occurrence of abnormality, easy blockage of a filling hole and the like, and is not suitable for sulfur deposition treatment of the ultra-deep sulfur-containing gas well shaft;
in the heating and melting method, the annular heating is suitable for shallow wells, and the sealing packer between the annular bottom oil pipe and the annular space is easy to fail; the method for filling the shaft with the coiled tubing is high in cost, the construction operation risk of the sulfur-containing gas well is high, and the coiled tubing 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 sour gas well wellbores.
Disclosure of Invention
The invention aims to overcome the defects of high sulfur deposition cost, high construction operation risk and the like of an ultra-deep sulfur-containing gas well in the prior art through solvent dissolution or heating and melting treatment, and provides a method for treating sulfur deposition in a shaft of the ultra-deep sulfur-containing gas well so as to achieve the purpose of efficiently removing sulfur deposition of the ultra-deep gas well at low cost.
The purpose of the invention is realized by the following technical scheme:
a sulfur deposition treatment method for the shaft of super-deep sulfur-containing gas well includes such steps as injecting sulfur solvent into shaft until the sulfur deposition is formed, closing the shaft for at least two days until the sulfur solvent flows down along the wall of shaft, gasifying, raising the pressure of well mouth, opening the shaft, returning the residual liquid of sulfur solvent, and collecting the residual liquid.
The method comprises the steps of accurately determining the sulfur deposition position, injecting a sulfur solvent into the gas well, closing the well from the sulfur deposition position to the wellhead position to enable the sulfur solvent to fully flow and vaporize along the well wall, increasing the contact time of liquid and solid-phase elemental sulfur, fully performing dissolution reaction, generating a vaporization effect by utilizing the temperature of the ultra-deep gas well, reducing the liquid column pressure of a shaft, realizing the return discharge of residual liquid and further realizing the treatment of sulfur deposition. The method has obvious treatment effect on the 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 purposes 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 the sulfur deposition location: determining the pressure and the temperature of a sulfur deposition position formed in 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 amount of sulfur solvent used: 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 shaft of the gas well, and the adding volume of the sulfur solvent is determined through a shaft volume calculation formula;
s3 sulfur solvent injection: according to not higher than 0.2m3Injecting sulfur solvent into the shaft at the discharge capacity of/min, so that the liquid flows downwards along the wall surface, and the height of a liquid column in the shaft is reduced;
s4 well closing reaction: when the sulfur solvent is injected into the shaft, the liquid column pressure of the sulfur solvent is formed, so that the residual liquid in the later period is difficult to flow back, the shaft is closed for more than 2 days, and the liquid column flows downwards along the wall surface of the shaft under the action of gravity, so that the sulfur solvent is accelerated to dissolve elemental sulfur by using the high temperature of the shaft, and the pressure of the liquid column is reduced, so that the pressure of the shaft mouth in the later period is convenient to rise;
s5, opening a well and reversely discharging: and after the well shut-in is finished, taking the gas flow of reasonable production allocation as a reference object, adjusting the gas flow, and quickly discharging and collecting the residual sulfur solvent.
The specific formula of the sulfur solvent is determined by taking dimethyl disulfide as a main body and matching with a catalyst, a hydrate inhibitor and a corrosion inhibitor; the intersection point of a shaft pressure-temperature curve and a gas well elemental sulfur phase diagram is used as a shaft sulfur deposition position, a sulfur deposition site is determined compared with a thermodynamic calculation method, and the sulfur deposition position is obtained through the intersection point of an elemental sulfur phase diagram plate obtained through experiments and a real-time shaft pressure-temperature curve. And then, the volume of the upper shaft at the sulfur deposition position is used as the addition amount of the sulfur solvent, the sulfur solvent is filled in a small-displacement mode, the well is closed for a period of time, the sulfur solvent is fully fluidized and vaporized, the pressure of the well mouth is promoted, and then gas discharge is carried out in stages, so that the sulfur solvent liquid after the sulfur deposition is dissolved can be rapidly discharged out of the shaft under the action of flowing gas, and the purposes of low cost and high efficiency are achieved.
Preferably, for further cost-effective purposes, the wellbore pressure-temperature curve is determined by a combination of downhole wireline pressure and a thermometer in real time. The gas pressure in the shaft is accurately measured by simple steel wire pressure, namely the steel wire with a pressure gauge is placed 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 measurement of the pressure-temperature curve is carried out by using a simple measuring method, and the aim of low cost is fulfilled.
Preferably, in order to further achieve the purpose of removing sulfur deposits of the ultra-deep gas well with low cost and high efficiency, the sulfur solvent is injected into a shaft of the gas well by using the injection pump, the injection pump is replaced by the injection pump to inject the sulfur solvent into an annular space or a capillary tube into an oil pipe, and small-displacement injection is carried out.
Preferably, in step S5, the adjusting of the gas flow rate includes a first stage and a second stage, the first stage sets the gas flow rate to be 1.5-2 times of the rational production gas flow rate, the second stage adjusts the gas flow rate to the rational production gas flow rate, and the condition of entering the second stage is that the wellhead pressure recovery is stable. The gas flow at the initial stage of liquid drainage is set to be 1.5 times of the gas flow of rational production allocation by taking the gas flow of rational production allocation as a reference, so that the discharge of the residual liquid of the sulfur solvent is accelerated, and the aim of efficiently removing the sulfur deposit of the ultra-deep gas well is fulfilled.
Preferably, for the purpose of further realizing the 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 position of H-sulfur deposition corresponds to the wellbore depth in units of: m;
r-wellbore inside radius, unit: m;
a pi-circumference ratio coefficient;
v-sulfur solvent amount, unit: m is3(ii) a The volume of the upper cylinder at the sulfur deposition position is used as the adding 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 at low cost is realized.
Preferably, in order to further achieve the purpose of efficiently removing sulfur deposits of the ultra-deep gas well, the sulfur solvent can rapidly flow along the well wall under the action of self gravity, the flow rate can reach 1000 meters per two hours, and the vaporization effect is generated at 50-100 ℃ or above.
Wherein the vaporization effect refers to: at high temperature and large surface area, liquid molecules absorb little vaporization heat (latent heat of vaporization), intermolecular attraction is overcome, the molecular distance is increased, and the liquid molecules are changed into gas molecules, namely, the liquid is more easily vaporized into gas at high temperature and large surface area, and the pressure of a liquid column in a shaft is reduced.
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 by mass percent, wherein WD11 is a corrosion inhibitor and can prevent or slow down material corrosion, and the balance is made up by water;
further, the sulfur solvent is a mixture of 15 percent of dimethyl disulfide, 3 percent of polyalkylene hydroxylamine, 10 percent of glycol and 2 percent of WD11 in percentage by mass; dimethyl disulfide is used as a purification solvent, polyalkylene hydroxylamine is used as a catalyst to catalyze a sulfur solvent to react with sulfur deposition, ethylene glycol is used as an inhibitor of hydrate to prevent hydrate from being formed in the sulfur solvent, WD11 is used as a corrosion inhibitor to prevent a pipeline from being corroded in a sulfur deposition dissolving stage, and therefore the purpose of efficiently removing sulfur deposition of an ultra-deep gas well is achieved.
The invention has the beneficial effects that:
1. the intersection point of a shaft pressure-temperature curve and an elemental sulfur solidification line in a gas well elemental sulfur phase diagram is used as a shaft sulfur deposition position, compared with a thermodynamic calculation method, a sulfur deposition site is determined, an obtained result is more accurate, then the upper shaft volume of the sulfur deposition position is used as the addition amount of a sulfur solvent, the sulfur solvent is filled in a small-displacement mode, meanwhile, a well is closed for a period of time, the sulfur solvent is fully dissolved, the pressure of a well mouth is promoted to be increased, then gas emission is carried out in stages, and the sulfur solvent liquid after sulfur deposition is dissolved can be rapidly discharged out of the shaft under the action of pressure, so that the purposes of low cost and high efficiency are achieved.
2. The pressure gauge is placed down by a simple steel wire, the pressure in the shaft is accurately measured, and the thermometer is used for measuring the real-time temperature in the shaft, so that the data measurement of a pressure-temperature curve is carried out by using a simple measurement method, and the purpose of true and reliable data is realized.
3. Carry out little discharge capacity filling through oil pipe, for annular space pump injection and capillary pump injection, this pump injection mode is safer, easy operation, and the working cost is low, and the well closing stifled well mode for a long time of cooperation can impel sulphur solvent fully to flow along the wall of a well and vaporize, increases liquid and solid phase simple substance sulphur contact time, and then fully dissolves the reaction, also can reduce pit shaft liquid column pressure, does benefit to the raffinate and flowbacks to realize the purpose of the sulphur deposit of low-cost high-efficient getting rid of super deep gas well.
4. By taking the gas flow of reasonable production allocation as a reference, the gas flow of the initial liquid discharge stage is set to be 1.5-2.0 times of the gas flow of the reasonable production allocation, so that the discharge of residual sulfur solvent is accelerated, the rapid discharge of sulfur deposition after dissolution is accelerated, and the purpose of efficiently removing the sulfur deposition of the ultra-deep gas well is realized.
5. The volume of the upper cylinder at the sulfur deposition position is used as the adding 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 at low cost is realized.
6. Dimethyl disulfide is used as a purification solvent, polyalkylene hydroxylamine is used as a catalyst to catalyze the dissolution of sulfur deposition, ethylene glycol is used as an inhibitor of hydrate to prevent hydrate from being formed in the sulfur solvent, WD11 is used as a corrosion inhibitor to prevent a pipeline from being corroded in the sulfur deposition dissolution stage, and therefore the purpose of efficiently removing sulfur deposition of an ultra-deep gas well is achieved.
Drawings
FIG. 1 is a schematic view of the determination of the sulfur deposit formation position of the present invention.
Detailed Description
The technical solutions of the present invention are further described in detail below with reference to the accompanying drawings, but the scope of the present invention is not limited to the following.
The gas well in a certain area is taken as a research object, the depth of a shaft of the gas well reaches 6000-7000 m, the content of hydrogen sulfide reaches more than 5%, the gas well has the characteristics of ultra-deep and high sulfur content, the pressure of the shaft of the existing gas well is reduced to be below 20MPa, the temperature is reduced to be below 30 ℃, the shaft is easy to generate sulfur deposition, the shaft of the gas well is blocked, and the gas release is influenced.
Example 1
1# well sulfur deposition remediation
A method for treating sulfur deposition in a shaft of an ultra-deep sulfur-containing gas well is characterized in that the shaft of a No. 1 gas well is 6800 meters deep, the gas release capacity caused by sulfur deposition is reduced to 20 ten thousand square per day from 40 ten thousand square per day, and the gas release capacity is continuously reduced;
a pressure gauge and a thermometer are put into a shaft through a steel wire, a shaft pressure-temperature curve is determined, a gas well elemental sulfur phase diagram 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 in the shaft of the gas well, and the depth of the shaft corresponding to the sulfur deposition position is 5000 meters, as shown in figure 1;
calculating the dosage of the sulfur solvent according to the sulfur deposition position, wherein the dosage of the sulfur solvent is the volume of an upper shaft of the sulfur deposition forming position in the shaft of the gas well, and the adding volume of the sulfur solvent is determined by a shaft volume calculation formula; the calculated upper wellbore volume from the sulfur deposit formation location was 22.5 square, i.e., the added volume of sulfur solvent was 22.5 square;
at 0.15m3Injecting sulfur solvent into a shaft to a sulfur deposition forming position at a discharge capacity of/min, after closing the well for 3 days, increasing the pressure of a well mouth to 15MPa, opening the well and returning the well with large yield, wherein the production allocation of the 1# well is 40 ten thousand square/day, setting the gas flow to be 60 ten thousand square/day in the first stage, namely the initial stage of well opening liquid drainage, and adjusting the gas flow to be 40 ten thousand square/day after the oil pressure of the well mouth is completely recovered to 20MPa and is kept stable; in this example, the self-formulated sulfur solvent was an aqueous mixture of dimethyl disulfide, polyalkylene hydroxylamine, ethylene glycol, and WD11 (available from Su-Ishiki France); the sulfur solvent is a water solution of a mixture of 15 percent of dimethyl disulfide, 3 percent of polyalkylene hydroxylamine, 10 percent of glycol and 2 percent of WD11 in percentage by mass; dimethyl disulfide is used as a purification solvent, polyalkylene hydroxylamine is used as a catalyst to catalyze the dissolution of sulfur deposition, ethylene glycol is used as an inhibitor of hydrate to prevent hydrate from being formed in the sulfur solvent, WD11 is used as a corrosion inhibitor to prevent a pipeline from being corroded in the sulfur deposition dissolution stage, and therefore the purpose of efficiently removing sulfur deposition of an ultra-deep gas well is achieved.
In the embodiment, only one component formula of a specific sulfur solvent is adopted, and in the sulfur deposition treatment process, the used sulfur solvent only needs to generate a vaporization effect under the self gravity and the temperature of not lower than 50 ℃, and can rapidly flow along the well wall and dissolve sulfur, so that the sulfur deposition treatment process is not limited to the component formula of the sulfur solvent.
After the sulfur deposition treatment is carried out by the method of the embodiment, the production allocation of the 1# well is recovered to 40 ten thousand square/day, the construction operation cost is only 10 ten thousand yuan, and hydrogen sulfide leakage does not occur.
Example 2
2# well sulfur deposition remediation
A method for treating sulfur deposition in a shaft of an ultra-deep sulfur-containing gas well is characterized in that the shaft of a No. 2 gas well is 6850 m deep, the gas release capacity caused by sulfur deposition is reduced to 20 ten thousand square per day from 40 ten thousand square per day, and the gas release capacity is continuously reduced;
a pressure gauge and a thermometer are put into a shaft through a steel wire, a shaft pressure-temperature curve is determined, a gas well elemental sulfur phase diagram 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 in the shaft of the gas well, and the depth of the shaft is 4500 m corresponding to the sulfur deposition position;
calculating the dosage of the sulfur solvent according to the sulfur deposition position, wherein the dosage of the sulfur solvent is the volume of an upper shaft of the sulfur deposition forming position in the shaft of the gas well, and the adding volume of the sulfur solvent is determined by a shaft volume calculation formula; the calculated upper wellbore volume from the sulfur deposit formation location was 20.25 square, i.e., the added volume of sulfur solvent was 20.25 square;
at 0.2m3Injecting sulfur solvent into a shaft to a sulfur deposition forming position at a discharge capacity of/min, after closing the well for 3 days, increasing the pressure of a well mouth to 16MPa, opening the well and returning the well with large yield, wherein the production allocation of the 2# well is 40 ten thousand square/day, and in the first stage, namely the initial stage of well opening and liquid drainage, setting the gas flow to be 70 ten thousand square/day, and after the oil pressure of the well mouth is completely recovered to 22MPa and is kept stable, adjusting the gas flow to be 40 ten thousand square/day; in this example, the sulfur solvent used was identical to well # 1.
After the sulfur deposition treatment is carried out by the method of the embodiment, the production allocation of the 2# well is recovered to 40 ten thousand square/day, the construction operation cost is only 10 ten thousand yuan, and hydrogen sulfide leakage does not occur.
Example 3
3# well sulfur deposition remediation
A method for treating sulfur deposition in a shaft of an ultra-deep sulfur-containing gas well is characterized in that the shaft of a 3# gas well is 6500 meters deep, the gas release capacity caused by sulfur deposition is reduced to 5 ten thousand parts per day from 20 ten thousand parts per day, and the gas release capacity is continuously reduced;
a pressure gauge and a thermometer are put into a shaft through a steel wire, a shaft pressure-temperature curve is determined, a gas well elemental sulfur phase diagram 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 in the shaft of the gas well, and the depth of the shaft corresponding to the sulfur deposition position is 5200 m;
calculating the dosage of the sulfur solvent according to the sulfur deposition position, wherein the dosage of the sulfur solvent is the volume of an upper shaft of the sulfur deposition forming position in the shaft of the gas well, and the adding volume of the sulfur solvent is determined by a shaft volume calculation formula; the calculated upper wellbore volume from the sulfur deposit formation location was 23.4 square, i.e., the volume of sulfur solvent added was 23.4 square;
at 0.1m3Injecting sulfur solvent into a shaft to a sulfur deposition forming position at a discharge capacity of/min, after closing the well for 5 days, increasing the pressure of a well mouth to 8MPa, opening the well and returning the well with large yield, wherein the production allocation of the 3# well is 20 ten thousand square/day, and in the first stage, namely the initial stage of well opening and liquid drainage, setting the gas flow to be 40 ten thousand square/day, and after the oil pressure of the well mouth is completely recovered to 12MPa and is kept stable, adjusting the gas flow to be 20 ten thousand square/day; in this example, the sulfur solvent used was identical to well # 1.
After the sulfur deposition treatment is carried out by the method of the embodiment, the production allocation of the 3# well is recovered to 20 ten thousand square/day, the construction operation cost is only 10 ten thousand yuan, and hydrogen sulfide leakage does not occur.
Comparative example 1
4# well sulfur deposition remediation
A method for treating sulfur deposition in a shaft of an ultra-deep sulfur-containing gas well is characterized in that the shaft of a 4# gas well is 6800 meters deep, the gas release capacity caused by sulfur deposition is reduced to 10 ten thousand square per day from 40 ten thousand square per day, and the gas release capacity is continuously reduced;
a pressure gauge and a thermometer are put into a shaft through a steel wire, a shaft pressure-temperature curve is determined, a gas well elemental sulfur phase diagram 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 in the shaft of the gas well, and the depth of the shaft corresponding to the sulfur deposition position is 5000 meters;
calculating the dosage of the sulfur solvent according to the sulfur deposition position, wherein the dosage of the sulfur solvent is the volume of an upper shaft of the sulfur deposition forming position in the shaft of the gas well, and the adding volume of the sulfur solvent is determined by a shaft volume calculation formula; the calculated upper wellbore volume from the sulfur deposit formation location was 22.5 square, i.e., the added volume of sulfur solvent was 22.5 square;
at 0.5m3Injecting a sulfur solvent into a shaft at a discharge capacity of/min until a sulfur deposition forming position, after closing the shaft for 3 days, increasing the pressure of a well mouth to 2MPa, and because the oil pressure of the well mouth is recovered to be lower, the well can not be opened at a large discharge capacity, and residual liquid is discharged at a large yield, at the first stage, namely the initial stage of the liquid discharging of the well opening, the maximum discharge capacity of a gas well is only 5 ten thousand square/day, and when the oil pressure of the well mouth is completely recovered to 10MPa and is kept stable, the maximum flow of the gas is only increased to 10 ten thousand square/day and is continuously reduced, so that the treatment effect is poor; in this example, the sulfur solvent used in this comparative example was the same as the sulfur solvent used to treat the # 1 well of example 1.
After the sulfur deposition treatment is carried out by the method of the comparative example, the production allocation of the 4# well is recovered to 10 ten thousand square/day and is continuously reduced, the construction operation cost is 10 ten thousand yuan, and hydrogen sulfide leakage does not occur.
Comparative example 2
5# well sulfur deposition remediation
A method for treating sulfur deposition in a shaft of an ultra-deep sulfur-containing gas well is characterized in that the shaft of a No. 5 gas well is 6800 meters deep, the gas release capacity caused by sulfur deposition is reduced to 20 ten thousand square per day from 40 ten thousand square per day, and the gas release capacity is continuously reduced;
a pressure gauge and a thermometer are put into a shaft through a steel wire, a shaft pressure-temperature curve is determined, a gas well elemental sulfur phase diagram 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 in the shaft of the gas well, and the depth of the shaft corresponding to the sulfur deposition position is 5000 meters;
calculating the dosage of the sulfur solvent according to the sulfur deposition position, wherein the dosage of the sulfur solvent is the volume of an upper shaft of the sulfur deposition forming position in the shaft of the gas well, and the adding volume of the sulfur solvent is determined by a shaft volume calculation formula; the calculated upper wellbore volume from the sulfur deposit formation location was 22.5 square, i.e., the added volume of sulfur solvent was 22.5 square;
at 0.15m3Displacement into the shaftInjecting a sulfur solvent to a sulfur deposition forming position, after closing the well for half a day, increasing the pressure of the well mouth to 1MPa, and because the oil pressure of the well mouth is recovered to be lower, the well opening with large discharge capacity cannot be realized, and residual liquid is discharged back with large yield, in the first stage, namely the initial stage of the well opening and liquid discharging, the maximum discharge capacity of a gas well is only 5 ten thousand per day, and when the oil pressure of the well mouth is completely recovered to 15MPa and is kept stable, the maximum flow of the gas is only increased to 20 ten thousand per day and is continuously reduced, so that the treatment effect is poor; in this example, the sulfur solvent used in this comparative example was the same as the sulfur solvent used to treat the # 1 well of example 1.
After the sulfur deposition treatment is carried out by the method of the comparative example, the production allocation of the 5# well is recovered to 20 ten thousand square/day and is continuously reduced, the construction operation cost is 10 ten thousand yuan, and hydrogen sulfide leakage does not occur.
Comparative example 3
6# well sulfur deposition remediation
A method for treating sulfur deposition in a shaft of an ultra-deep sulfur-containing gas well is characterized in that the shaft of a 5# gas well is 7000m deep, the gas release capacity caused by sulfur deposition is reduced to 10 ten thousand square per day from 40 ten thousand square per day, and the gas release capacity is continuously reduced;
a pressure gauge and a thermometer are put into a shaft through a steel wire, a shaft pressure-temperature curve is determined, a gas well elemental sulfur phase diagram 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 in the shaft of the gas well, the corresponding shaft depth is 5000 meters of the sulfur deposition position, the calculated upper shaft volume of the sulfur deposition forming position is 22.5 square, namely the adding volume of a sulfur solvent is 22.5 square;
the coiled tubing is put into the 5000m position of the shaft with the diameter of 0.15m3Injecting sulfur solvent into a shaft through a continuous oil pipe at a discharge capacity of/min, after closing the well for 3 days, increasing the pressure of a well mouth to 16MPa, opening the well and returning the well with large yield, wherein the production allocation of the 6# well is 40 ten thousand square/day, and setting the gas flow to be 60 ten thousand square/day in the first stage, namely the initial stage of well opening liquid drainage, till the oil pressure of the well mouth is completely recovered to 20MPa and is kept stable, and adjusting the gas flow to be 40 ten thousand square/day; the sulfur solvent used in this comparative example was the same as that used in example 1 to treat the # 1 well.
After sulfur deposition treatment by the method of the comparative example, the production allocation of the 6# well is recovered to 40 ten thousand square per day, the construction operation cost reaches 100 ten thousand yuan, and hydrogen sulfide leakage occurs.
Comparative example 4
7# well sulfur deposition remediation
The well bore of the 7# gas well is 7000 meters deep, and the gas release capacity caused by sulfur deposition is reduced from 40 ten thousand square/day to 10 ten thousand square/day and is continuously reduced;
determining a sulfur deposition position by adopting a thermodynamic calculation method based on temperature data and gas flow data, wherein the position corresponding to the 4000 meter of shaft depth is a sulfur deposition forming 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 5000-meter shaft is a sulfur deposition forming position, and the adding volume of a sulfur solvent is 4000-meter depth volume, namely 18 square;
at 0.15m3Injecting sulfur solvent into a shaft with the discharge capacity of/min till the position of sulfur deposition is formed, closing the well for 3 days, increasing the pressure of a well mouth to 15MPa, opening the well for large-yield flow back, and adjusting the production rate of a 7# well to 40 ten thousand square/day, wherein in the first stage, namely the initial stage of opening the well for liquid discharge, the gas flow is set to be 60 ten thousand square/day, and when the oil pressure of the well mouth is completely recovered to 20MPa, and the gas flow is adjusted to be 40 ten thousand square/day after the oil pressure is kept stable; the sulfur solvent used in this comparative example was the same as that used in example 1 to treat the # 1 well.
After sulfur deposition treatment by the method of the comparative example, the yield of the 7# well is recovered to 40 ten thousand square per day, but the yield is continuously reduced, the construction operation cost is 10 ten thousand yuan, and hydrogen sulfide leakage does not occur.
Comparative example 5
8# well sulfur deposition remediation
The well bore of the 8# gas well is 6800 meters deep, and the gas release capacity caused by sulfur deposition is reduced from 40 ten thousand square/day to 20 ten thousand square/day and is continuously reduced;
determining the 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 the sulfur deposition forming position, namely the position is 22.5 square;
at 0.15m3Injecting sulfur solvent into the shaft with the discharge capacity of/min till the position of sulfur deposition is formed, closing the well for 3 days, raising the pressure of a well mouth to 15MPa, opening the well for large-yield flow back, controlling the production rate of the 8# well to be 40 ten thousand square/day, and performing shaft drainage in stages without stages, namely keeping the 40 ten thousand square/day production of the gas well till the pressure of the well mouth is recovered to 20 MPa; the sulfur solvent used in this comparative example was the same as that used in example 1 to treat the # 1 well.
After the sulfur deposition treatment is carried out by the method of the comparative example, the yield of the 8# well is recovered to 40 ten thousand square/day, but the sulfur deposition in the shaft is not completely discharged, so that the blockage and the throttling exist, and the yield is continuously reduced. The construction cost is 10 ten thousand yuan, and no hydrogen sulfide leakage occurs.
The cumulative recovery gas flow rate, construction work cost and hydrogen sulfide leakage were counted up over 30 days comparing examples 1 to 3 and comparative examples 1 to 5, and table 1 was obtained.
TABLE 1 comparative tables of examples 1-3 and comparative examples 1-5
As can be seen from table 1, when the determination of the sulfur deposition position is performed by referring to the saturated elemental sulfur precipitation curve through the wellbore pressure-temperature curve and the gas well elemental sulfur phase diagram, and an aqueous solution of a mixture of 15% of dimethyl disulfide, 3% of polyalkylene hydroxylamine, 10% of ethylene glycol and 2% of WD11 is used as a sulfur solvent, and simultaneously, in a "small-displacement, long-immersion and large-flowback" tubing pump manner, after the sulfur deposition wellbore is treated by the method, the gas yield is obviously recovered, the cost is low, and hydrogen sulfide leakage does not occur; when the large-displacement short-time soaking is adopted, the formula and the dosage are the same, but the pressure for wellhead pressure rise is lower, so that the dissolving effect of the whole sulfur deposition is influenced; when the coiled tubing is used for pumping into a well bore, the formula, the dosage and the well shut-in time are the same, but the operation cost is high, and hydrogen sulfide leakage occurs; when the position of the sulfur deposition in the shaft is calculated by thermodynamics, the corresponding amount of the sulfur solvent is obtained, the formula, the pumping discharge and the well closing soaking time are the same, but the normal production allocation cannot be recovered, and the treatment effect is poor.
In summary, under the background that the development of gas fields at home and abroad generally tends to the development of ultra-deep sulfur-containing gas wells (accounting for 40% of natural gas reserves at home and abroad), the problem of sulfur deposition and blockage of gas well shafts is faced in the middle and later stages of the development of the gas fields, so that the method can be effectively applied to the treatment of the sulfur deposition of the shaft of the ultra-deep sulfur-containing gas well.
The foregoing is illustrative of the preferred embodiments of this invention, and it is to be understood that the invention is not limited to the precise form disclosed herein and that various other combinations, modifications, and environments may be resorted to, falling within the scope of the concept as disclosed herein, either as described above or as apparent to those skilled in the relevant art. And that modifications and variations may be effected by those skilled in the art without departing from the spirit and scope of the invention as defined by the appended claims.
Claims (9)
1. A sulfur deposition treatment method for a wellbore of a sulfur-containing gas well is characterized by comprising the following steps: and (3) injecting a sulfur solvent into the shaft to a sulfur deposition forming position, closing the well for at least two days, starting the well up to the pressure of the well mouth, and performing staged flowback when the well is opened, so that the sulfur deposition treatment is realized.
2. The method for treating sulfur deposition in the wellbore of a sulfur-containing gas well as recited in claim 1, wherein: the sulfur deposition treatment method specifically comprises the following steps:
s1 determining the sulfur deposition location: determining the pressure and the temperature of a sulfur deposition position formed in 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 shaft depth is the sulfur deposition position;
s2 determining the amount of sulfur solvent used: 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 shaft of the gas well, and the adding volume of the sulfur solvent is determined through a shaft volume calculation formula;
s3 sulfur solvent injection: according to not higher than 0.2m3Injecting sulfur solvent into the shaft at the discharge capacity of/min;
s4 well closing reaction: when the sulfur solvent is injected into the shaft, the liquid column pressure of the sulfur solvent is formed, the liquid column pressure is greater than the highest closing oil pressure of the gas well wellhead, the shaft is closed, the sulfur solvent flows downwards along the wall surface of the shaft and is vaporized under the action of temperature, the liquid column pressure is reduced, and the pressure of the shaft is kept;
s5, opening a well and reversely discharging: and after the well shut-in is finished, adjusting the gas flow by taking the gas flow of reasonable production allocation as a reference object, and flowback and collecting the residual sulfur solvent.
3. The method for treating sulfur deposition in the wellbore of a sulfur-containing gas well as recited in claim 2, wherein: the shaft pressure-temperature curve is obtained by real-time combined measurement of the pressure of a steel wire put in the shaft and a thermometer.
4. The method for treating sulfur deposition in the wellbore of a sulfur-containing gas well as recited in claim 2, wherein: a sulfur solvent is injected directly into the wellbore using a charge pump.
5. The method for treating sulfur deposition in the wellbore of a sulfur-containing gas well as recited in claim 2, wherein: in step S5, the adjusting of the gas flow rate includes a first stage and a second stage, the first stage sets the gas flow rate to be 1.5-2 times of the gas flow rate of the rational production allocation, the second stage adjusts the gas flow rate to the gas flow rate of the rational production allocation, and the condition of entering the second stage is that the wellhead oil pressure is recovered stably.
6. The method for treating sulfur deposition in the wellbore of a sulfur-containing gas well as recited in claim 2, wherein: the volume formula of the gas well shaft is as follows:
V＝π*r2*H
wherein the position of H-sulfur deposition corresponds to the wellbore depth in units of: m;
r-wellbore inside radius, unit: m;
a pi-circumference ratio coefficient;
v-sulfur solvent amount, unit: m is3。
7. The sulfur deposition abatement method for the wellbore of a sulfur-containing gas well according to claim 1 or 2, wherein: the sulfur solvent is required to generate vaporization effect under the self gravity and the temperature of not lower than 50 ℃, and the sulfur solvent can rapidly flow along the well wall.
8. The method for treating sulfur deposition in the wellbore of a sulfur-containing gas well as recited in claim 7, wherein: the sulfur solvent is an aqueous mixture comprising dimethyl disulfide, polyalkylene hydroxylamine, ethylene glycol, and WD 11.
9. The method for treating sulfur deposition in the wellbore of a sulfur-containing gas well as recited in claim 8, wherein: the sulfur solvent comprises the following raw materials in percentage by mass: 10-20% of dimethyl disulfide, 2-5% of polyalkylene hydroxylamine, 5-15% of ethylene glycol and 1-5% of WD11, the balance being water.
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