CN103670352B - Automatic control method for removing accumulated liquid in gas well - Google Patents
Automatic control method for removing accumulated liquid in gas well Download PDFInfo
- Publication number
- CN103670352B CN103670352B CN201210348123.5A CN201210348123A CN103670352B CN 103670352 B CN103670352 B CN 103670352B CN 201210348123 A CN201210348123 A CN 201210348123A CN 103670352 B CN103670352 B CN 103670352B
- Authority
- CN
- China
- Prior art keywords
- gas well
- liquid
- gas
- formula
- long
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 239000007788 liquid Substances 0.000 title claims abstract description 145
- 238000000034 method Methods 0.000 title claims abstract description 33
- 239000007789 gas Substances 0.000 claims abstract description 205
- 238000004519 manufacturing process Methods 0.000 claims abstract description 51
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims abstract description 20
- 238000004458 analytical method Methods 0.000 claims abstract description 10
- 239000003345 natural gas Substances 0.000 claims abstract description 10
- 238000004364 calculation method Methods 0.000 claims abstract description 8
- 239000012530 fluid Substances 0.000 claims description 10
- 238000005553 drilling Methods 0.000 claims description 9
- 230000009467 reduction Effects 0.000 claims description 7
- 235000009508 confectionery Nutrition 0.000 claims description 6
- 239000000203 mixture Substances 0.000 claims description 5
- 230000003068 static effect Effects 0.000 claims description 5
- 238000000605 extraction Methods 0.000 abstract description 3
- 238000009825 accumulation Methods 0.000 abstract 1
- 239000012071 phase Substances 0.000 description 16
- 230000008569 process Effects 0.000 description 7
- 230000008859 change Effects 0.000 description 4
- 230000007423 decrease Effects 0.000 description 4
- 239000003814 drug Substances 0.000 description 4
- 230000005540 biological transmission Effects 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 3
- 238000011084 recovery Methods 0.000 description 3
- 239000003795 chemical substances by application Substances 0.000 description 2
- 238000007599 discharging Methods 0.000 description 2
- 239000006260 foam Substances 0.000 description 2
- 230000008676 import Effects 0.000 description 2
- 239000007791 liquid phase Substances 0.000 description 2
- 241001269238 Data Species 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000006071 cream Substances 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 229940079593 drug Drugs 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
Landscapes
- Earth Drilling (AREA)
Abstract
The invention discloses an automatic control method for removing accumulated liquid from a gas well, which comprises the following steps: 200, collecting related parameters of gas well effusion; step 300, analyzing and calculating the collected parameters related to the gas well accumulated liquid through a formula, judging whether the gas well accumulated liquid exists, if so, executing step 400, and if not, executing step 200; and step 400, executing a dosing instruction according to the analysis and calculation result. According to the method, whether the gas well is accumulated liquid or not can be accurately judged in time by judging the liquid accumulation software and combining the collected parameters related to the gas well liquid accumulation, and the liquid accumulation software can be quickly and massively processed, so that the normal production of the gas well and the extraction degree of natural gas are greatly promoted.
Description
Technical field
The present invention relates to Natural gas extraction field, in particular to a kind of by judging that the whether long-pending liquid of gas well instructs gas well to get rid of the autocontrol method of long-pending liquid.
Background technology
In the process of gas field Natural gas extraction, along with going deep into of exploitation, the decline gradually of producing energy, formation water output also occurs thereupon, and natural-gas fluid-carrying capability weakens, the long-pending liquid of pit shaft is caused day by day to increase, if long-pending for pit shaft liquid can not be discharged in time, wellhead pressure can be caused to reduce, thus increase liquid to the back pressure of gas-bearing formation, cause gas production sharply to decline, the phenomenon of dried-up well even occurs. For long-pending liquid gas well, most widely used is filling foam discharging agent bubble row's draining gas production measure, generally adopts and passes through oil cover annular space filling in bubble row's car well head filling or gas gathering station, and filling foam discharging agent has suitability by force, the advantages such as cream time is short, discharge opeing successful.
At present, traditional gas well plug-ging determination methods is only the change by oil casing pressure and output tolerance, is undertaken judging whether long-pending liquid by artificial experience, and controls manually to carry out dosing discharge opeing by judged result.
In the process realizing the present invention, contriver finds that prior art at least exists following problem:
Utilize traditional gas well plug-ging determination methods, only when the stage that gas well plug-ging is more serious, just can judge that pit shaft amasss liquid, gas well plug-ging situation can not be reflected in time, and judgement is played a major role by artificial experience, lack reliability, seriously have impact on the recovery percent of reserves of the normal production of gas well and Sweet natural gas.
Summary of the invention
Gas well plug-ging situation can not be reflected in time, and artificial experience lacks the problem of reliability, embodiments provides the autocontrol method that long-pending liquid got rid of by a kind of gas well to solve prior art. Described technical scheme is as follows:
An autocontrol method for long-pending liquid got rid of by gas well, and described autocontrol method comprises the steps:
Step 200, gathers the parameter that gas well plug-ging is relevant;
Step 300, by parameter relevant for the described gas well plug-ging that collects, carries out analytical calculation by formula, judges the whether long-pending liquid of described gas well, if there is long-pending liquid to perform step 400, if there is no long-pending liquid performs step 200;
Step 400, performs dosing instruction according to analysis result.
Specifically, as preferably, described step 200 gathers the gas production rate that the relevant parameter of gas well plug-ging is oil pressure, casing pressure and gas well, gathers the described oil pressure of described gas well and described casing pressure parameter especially by pressure transmitter, gathered the gas production rate of described gas well by under meter.
Specifically, as preferably, described step 300 carrying out analytical calculation according to following basis for estimation, a)-f is specifically comprised) six kinds of formula:
A) formula
V<vc
In formula: pit shaft gas liquid mixture flow velocity described in V, is gathered by described under meter and calculate,
vcCritical take flow velocity, �� liquid-gas interface tension force, ��lFluid density, ��gGas density, A=-0.9622ln (GWR)+13.757, A critical flow velocity correction factor, zero dimension, GWR produces vapour-liquid ratio, GWR > 1370;
B) formula
pt0-pt1>0
In formula: Pt0Gas well with the casing pressure of scrubbed gas production phase, Pt1The casing pressure of a certain moment gas well;
C) formula
��pf1>��pf0
In formula: �� pf1The pressure drop of a certain moment gas well loss, i.e. proof wellhead oil casing pressure reduction, �� pf1=pc1-pt1, pc1The oil pressure of a certain moment gas well, pt1The casing pressure of a certain moment gas well; �� pf0Gas well with the pressure drop of scrubbed gas production phase loss, i.e. proof wellhead oil casing pressure reduction, �� pf0=pc0-pt0, pc0Gas well with the oil pressure of scrubbed gas production phase, pt0Gas well is with the casing pressure of scrubbed gas production phase;
D) formula
pt3-pt2>0
In formula: Pt2And Pt3Refer to the gas well formerly casing pressure data in latter two different time sections;
E) formula
qg-qg0>0
Above formula prerequisite is under the geostationary condition of static pressure Pr of stratum,
In formula: qgThe gas production rate in gas well a certain moment, qg0Relative to qgThe gas production rate of gas well at the end of a front complete discharge opeing;
F) formula
p1-p2>0
In formula: P1And P2Refer to the gas well formerly pressure of the well head stream in latter two different time sections data;
The above formula a)-f) in when at least meeting any three, then determine that described gas well has pit shaft to amass liquid, continue to perform step 400, otherwise perform step 200.
Specifically, as preferably, described step 400 is concrete to be performed according to the following steps:
Step 401, if described formula analysis result determines that described pit shaft amasss liquid, performs step 400, if described formula analysis result determines the not long-pending liquid of described pit shaft, performs described step 200;
Step 402, calculates the long-pending liquid measure of described pit shaft;
Step 403, according to the long-pending liquid measure of the described pit shaft calculated, control automatic fluid removing system determine to need filling except liquid dosage, and calculate the working time needing to start dispenser pump, thus described pit shaft inner product liquid carried out automatically except liquid.
Specifically, as preferably, the long-pending liquid measure calculating described pit shaft in described step 402 is according to following formulae discovery:
In formula: Q2The long-pending liquid measure of pit shaft, CgThe isothermal compressibility of Sweet natural gas; H' finishing drilling mine shaft depth; The tubing depth of H lower going-into-well cylinder, the diameter of D pit shaft, �� pcThe difference of the casing pressure of pit shaft different time sections, the equivalent height of �� H ' finishing drilling pit shaft inner product liquid, the equivalent height of �� H oil pipe inner product liquid.
Further, described autocontrol method also comprises step 100, described step 100 was implemented before described step 200, described step 100 is extract the basic parameter of gas well, and described basic parameter comprises tubing and casing size, gas relative density, finishing drilling mine shaft depth, the tubing depth of lower going-into-well cylinder and liquid-gas interface tension force.
The useful effect that the technical scheme that the embodiment of the present invention provides is brought is:
The present invention is by judging long-pending liquid software, in conjunction with the parameter with the long-pending liquid phase pass of gas well collected, to gas well whether long-pending liquid can promptly and accurately judge, and judge that long-pending liquid software can carry out fast and mass processes, greatly facilitate the normal production of gas well and the recovery percent of reserves of Sweet natural gas.
Accompanying drawing explanation
In order to the technical scheme being illustrated more clearly in the embodiment of the present invention, below the accompanying drawing used required in embodiment being described is briefly described, apparently, accompanying drawing in the following describes is only some embodiments of the present invention, for those of ordinary skill in the art, under the prerequisite not paying creative work, it is also possible to obtain other accompanying drawing according to these accompanying drawings.
Fig. 1 is the schematic flow sheet of the autocontrol method described in the embodiment of the present invention;
The schematic flow sheet of Fig. 2 autocontrol method described in an embodiment again provided by the invention.
Embodiment
For making the object, technical solutions and advantages of the present invention clearly, below in conjunction with accompanying drawing, embodiment of the present invention is described further in detail.
As shown in Figure 1, the autocontrol method of long-pending liquid got rid of by a kind of gas well, and described autocontrol method comprises the steps:
Step 200, gathers the parameter that gas well plug-ging is relevant;
Step 300, by parameter relevant for the described gas well plug-ging that collects, carries out analytical calculation by formula, judges the whether long-pending liquid of described gas well, if there is long-pending liquid to perform step 400, if there is no long-pending liquid performs step 200;
Step 400, performs dosing instruction according to analysis result.
Wherein, by computer programming technology, the method judging the whether long-pending liquid of gas well is compiled software, in judgement process, in conjunction with parameters such as the production datas relevant with gas well plug-ging collected, as the basic data of this computed in software, the associated static data of input gas well, also can the associated static data of gas well directly be enrolled in this software, this software passes through analytical calculation, the whether long-pending liquid of gas well can be judged, indicate whether that needs add except liquid medication carries out except liquid operation according to this judged result.
The present invention is by judging long-pending liquid software, utilize computer programming technology, achieve and change from pure theory to digitizing enforceability, in conjunction with the parameter with the long-pending liquid phase pass of gas well collected, the whether long-pending liquid of gas well can promptly and accurately be judged, and judge that long-pending liquid software can carry out fast and mass processes, greatly facilitate the normal production of gas well and the recovery percent of reserves of Sweet natural gas.
As shown in Figure 2, specifically, as preferably, described step 200 gathering the gas production rate that the relevant parameter of gas well plug-ging is oil pressure, casing pressure and gas well, gather the described oil pressure of described gas well and described casing pressure parameter especially by pressure transmitter, gathered the gas production rate of described gas well by under meter. The pressure transmitter that application gas well mouth is installed and under meter, monitor gas well real-time status, and gather correlation parameter in real time, by remote transmission to gas gathering station database server, uses for the long-pending liquid software analysis of judgement.
The whether long-pending liquid of gas well is judged according to actual production data, first gas well carries out critical liquid status of taking judge, critical liquid status of taking refers to that gas well scrubbed gas (without long-pending liquid) production phase and gas well produce the criticality in long-pending liquid stage, gather the gas production rate of the oil pressure of pit shaft reality, actual casing pressure and reality, calculate gas well at correlation parameters such as the casing pressures in theory without pit shaft when long-pending liquid, the casing pressure in theory of gas well, actual casing pressure and the two the relation such as change of difference above are carried out comprehensive interpretation.
Specifically, as preferably, described step 300 carrying out analytical calculation according to following basis for estimation, a)-f is specifically comprised) six kinds of formula:
A) formula
V<vc
Wherein, pit shaft gas liquid mixture flow velocity described in V, is gathered by described under meter and calculates; vcCritical take flow velocity, vcCalculate by following calculation formula:
In formula: �� liquid-gas interface tension force; ��lFluid density; ��gGas density;
A=-0.9622ln (GWR)+13.757, A critical flow velocity correction factor, zero dimension; GWR produces vapour-liquid ratio, GWR > 1370. Wherein, the real-time traffic of the gas liquid mixture of gas well can directly be measured by under meter, and flow is divided by the cross-sectional area of pit shaft, just the flow velocity of the gas liquid mixture of gas well output can be drawn, and those skilled in the art easily learn, all the other each parameters above all can directly obtain, so the flow velocity of pit shaft is less than and critical takes flow velocity, also the flow being the output of current gas well is less than the critical liquid carrying flow rate of gas well, can judge that gas well pit shaft amasss liquid. Using above formula to be calculated by the critical liquid carrying flow rate of Su Lige more than 900 mouth well, result and gas well actual production situation matching are better;
B) formula
At gas well with the scrubbed gas production phase, or the production phase of a upper complete discharge opeing, we can extrapolate oil pressure P at that timec0With casing pressure Pt0, and then the mill resistance f of scrubbed gas production phase can be tried to achieve, along with the carrying out produced, if producing long-pending liquid in a certain moment pit shaft, then the casing pressure of gas well can be caused to be declined to become Pt1, Pt1Obtain by pressure transmitter, by the correlative value of the actual casing pressure of gas well and theoretical casing pressure (the gas well casing pressure of scrubbed gas production phase) as pit shaft whether one of criterion amassing liquid;
pt0-pt1>0
In formula: Pt0Gas well with the casing pressure of scrubbed gas production phase, Pt1The casing pressure of a certain moment gas well.
C) formula
The scrubbed gas production phase, those skilled in the art can calculate the theoretical pressure drop �� p of lossf0, when if gas well does not amass liquid, the pressure drop �� p of gas well active lossf1Theoretical pressure drop �� p should be equaledf0If, and the pressure drop of a certain moment gas well loss, namely oil cover pressure reduction is greater than theoretical pressure drop �� pf0Time, then gas well may be produced by band liquid, wherein the oil pressure of a certain moment gas well and casing pressure pc0��pt0Obtain by pressure transmitter.
��pf1>��pf0
In formula: �� pf1The pressure drop of a certain moment gas well loss, i.e. proof wellhead oil casing pressure reduction, �� pf1=pc1-pt1, pc1The oil pressure of a certain moment gas well, pt1The casing pressure of a certain moment gas well; �� pf0Gas well with the pressure drop of scrubbed gas production phase loss, i.e. proof wellhead oil casing pressure reduction, �� pf0=pc0-pt0, pc0Gas well with the oil pressure of scrubbed gas production phase, pt0Gas well is with the casing pressure of scrubbed gas production phase.
D) formula
After the liquid level of the long-pending liquid in gas well shaft bottom rises and exceeds tubing shoe, casing pressure will rise, now show that gas well has serious shaft bottom and amasss liquid, casing pressure change more greatly, show that long-pending liquid is more many, Pt3It is later than P in timet2��
pt3-pt2>0
In formula: Pt2And Pt3Refer to the gas well formerly casing pressure data in latter two different time sections.
E) formula
When gas well band liquid is produced or liquid is amassed in shaft bottom, the relative gas well scrubbed gas production phase adds shaft bottom back pressure, thus make stratum drawdown pressure reduce stratum output and reduce, i.e. gas well gas production rate decline, under the geostationary condition of static pressure Pr of stratum, if the gas production rate in front a certain moment is less than the gas production rate at the end of a front complete discharge opeing, it may be that the result of the long-pending liquid of pit shaft, qgAnd qg0All can collect by under meter.
qg-qg0>0
In formula: qgThe gas production rate in gas well a certain moment, qg0Relative to qgThe gas production rate of gas well at the end of a front complete discharge opeing.
F) formula
After gas well liquid loading starts to produce long-pending liquid, if output long-pending liquid in stratum can not be taken out of in time, long-pending liquid measure will be more long-pending more many, produce in the flowing gas post of pit shaft, liquid distribution coefficient is increasing, the loss of pit shaft will increase gradually, and well head stream pressure will decline, i.e. well head stream pressure data P in latter two different time sections first1And P2, by pressure transmitter collection and calculate draw.
p1-p2>0
In formula: P1And P2Refer to the gas well formerly pressure of the well head stream in latter two different time sections data.
Described formula a)-f) in when at least meeting any three, then determine that described gas well has pit shaft to amass liquid, continue to perform step 400, otherwise perform step 200. In actual production process, due to the instability of some other factor, likely cause wherein certain formula can also set up when pit shaft does not amass liquid, so isolated considers having little significance of above-mentioned formula, in general, consider above formula a)-f), there are three to meet condition at least simultaneously, then can determine that pit shaft amasss liquid. This is judged, and long-pending liquid method and all formula pass through computer programming technical editor as software, namely realizes the long-pending liquid of pit shaft automatic decision.
As shown in Figure 2, specifically, as preferably, described step 400 is concrete to be performed according to the following steps:
Step 401, if described formula analysis result determines that described pit shaft amasss liquid, performs step 400, if described formula analysis result determines the not long-pending liquid of described pit shaft, performs described step 200;
Step 402, calculates the long-pending liquid measure of described pit shaft;
Step 403, according to the long-pending liquid measure of the described pit shaft calculated, control automatic fluid removing system determine to need filling except liquid dosage, and calculate the working time needing to start dispenser pump, thus described pit shaft inner product liquid carried out automatically except liquid.
Wherein, if it is determined that the not long-pending liquid of pit shaft, proceed the data gathering of a new round, and by judging that long-pending liquid software analysis calculates, if it is determined that the long-pending liquid of described pit shaft, then long-pending liquid judged result imports automatic fluid removing system in the form of data into, artificial in this system it is provided with database, for not equally having liquid measure, what from database, the long-pending liquid measure of automatic reading was corresponding adds except liquid dosage relation, analyze the time of the required startup filling of this well except the liquid pump wanted, send filling instruction subsequently, can by gas gathering station radio station and individual well radio station transmission instruction signal, thus command Adding medicine control case, realize intelligence Automatic Dosing function.
In actual production, gas well plug-ging is a process slowly, judges the computation process also more complicated of long-pending liquid software, so being set to by computation period adjustable, being traditionally arranged to be and can meet actual needs once a day.
Further, the long-pending liquid measure calculating described pit shaft in described step 402 is according to following formulae discovery:
In formula: Q2The long-pending liquid measure of pit shaft, CgThe isothermal compressibility of Sweet natural gas; H' finishing drilling mine shaft depth; The tubing depth of H lower going-into-well cylinder, the diameter of D pit shaft, �� pcThe difference of the casing pressure of pit shaft different time sections, the equivalent height of �� H ' finishing drilling pit shaft inner product liquid, the equivalent height of �� H oil pipe inner product liquid.
Wherein, pit shaft amasss liquid measure three's sum in the shaft bottom liquid measure and oil pipe that liquid measure is below annular space liquid measure, oil pipe pipe footwear, and namely the long-pending liquid measure of pit shaft can be write as: Q2=QRing+QThe end+QPipe
In formula, a part liquid measure is respectively by following formulae discovery:
1) annular space liquid measure QRing:
2) shaft bottom liquid measure Q below oil pipe pipe footwearThe end:
3) liquid measure Q in oil pipePipe
By the pressure drop of current a certain moment gas well loss, i.e. oil cover pressure differential deltap pf1=pc1-pt1, and gas well is at the pressure drop �� p of the theoretical friction of pure gas production phasef0=pc0-pt0, the additional energy loss �� p producing because of pit shaft and producing long-pending liquid and bring can be drawn:
��p=��pf1-��pf0
The equivalent height of liquid storage in oil pipe:
��H=100����p
To sum up, the long-pending liquid measure of pit shaft is:
The method judging the long-pending liquid of pit shaft and calculated product liquid measure above is passed through computer programming, form feasibility software, this software incorporates the automatic fluid removing system of gas well, and the result judged by the long-pending liquid of pit shaft by application software, instructs automatic fluid removing system to be carried out by pit shaft inner product liquid except liquid.
As shown in Figure 2, further, described autocontrol method also comprises step 100, described step 100 was implemented before described step 200, described step 100 is extract the basic parameter of gas well, and described basic parameter comprises tubing and casing size, gas relative density, finishing drilling mine shaft depth, the tubing depth of lower going-into-well cylinder and liquid-gas interface tension force. Different gas well basic parameters is not identical, inputs basic parameter in application software, by having the cooperation of related parameter to carry out judging to calculate to gas well plug-ging situation with gas well plug-ging; If for same gas well, various parameter is identical, it is also possible to directly enrolled by gas well basic parameter in the program of application software, directly is undertaken extracting calculating by software.
In embodiment as shown in Figure 2, by in the basic parameter of gas well input application software, gas well mouth gathers well head oil pressure and casing pressure in real time by pressure transmitter, under meter gathers single gas well instantaneous delivery in real time, the relevant uniform data of the various gas wells collected is pooled to RTU, and undertaken being wirelessly transmitted to gas gathering station radio station by well head radio station, stored in gas gathering station server, computing client terminal is by local area network network, the relevant in real time data judging the long-pending liquid of pit shaft are obtained from server, the whether long-pending liquid of pit shaft is gone out by computer programming software automatic decision, if it is determined that the not long-pending liquid of gas well, then perform step 200, continue image data, calculate judgement next time, if it is determined that gas well plug-ging, then given vent to anger the long-pending liquid measure of well shaft by formulae discovery, and in computer interface, judged result is shown, in this interface except demonstrating the whether long-pending liquid of this gas well and corresponding long-pending liquid measure, also list the basic parameter of this well and Production development data, such as the tubing and casing size of well, gas relative density, oil pressure, casing pressure and gas production rate etc., by this interface, can clearly understand the Production development situation that need to monitor well and long-pending liquid situation. long-pending liquid judged result imports automatic fluid removing system in the form of data into, for not equally having liquid measure, corresponding adds except liquid dosage, and automatically calculate the time needing to start dosing pump, send filling instruction subsequently, by gas gathering station radio station and individual well radio station transmission instruction signal, thus command individual well Adding medicine control case RTU, switch and working time to dosing pump control, when the filling of a bite well terminates, RTU can pass through electronic guidance Vavle switching automatically to another mouthful of well, until filling terminates, RTU controls pump shutdown, so realize intelligence Automatic Dosing function, by the lathering property except liquid medicine, the long-pending liquid of pit shaft is discharged the most at last, reach the object improving rate and Production Life when individual well opens well.
Above-mentioned embodiment of the present invention sequence number, just to describing, does not represent the quality of embodiment.
The foregoing is only the better embodiment of the present invention, not in order to limit the present invention, within the spirit and principles in the present invention all, any amendment of doing, equivalent replacement, improvement etc., all should be included within protection scope of the present invention.
Claims (5)
1. the autocontrol method amassing liquid got rid of by a gas well, it is characterised in that, described autocontrol method comprises the steps:
Step 200, gathers the parameter that gas well plug-ging is relevant;
Step 300, by parameter relevant for the described gas well plug-ging that collects, by judging that long-pending liquid software carries out analytical calculation, judges the whether long-pending liquid of described gas well, if there is long-pending liquid to perform step 400, if there is no long-pending liquid performs step 200;
Step 400, performs dosing instruction according to analysis result,
In described step 300, in the long-pending liquid software of described judgement, specifically comprise a)-f) six kinds of formula:
A) formula
V<vc
In formula: V pit shaft gas liquid mixture flow velocity, is gathered by under meter and calculate,
vcCritical take flow velocity, �� liquid-gas interface tension force, ��lFluid density, ��gGas density, A=-0.9622ln (GWR)+13.757, A critical flow velocity correction factor, zero dimension, GWR produces vapour-liquid ratio, GWR > 1370;
B) formula
pt0-pt1> 0
In formula: Pt0Gas well with the casing pressure of scrubbed gas production phase, Pt1The casing pressure of a certain moment gas well;
C) formula
��pf1> �� pf0
In formula: �� pf1The pressure drop of a certain moment gas well loss, i.e. proof wellhead oil casing pressure reduction, �� pf1=pc1-pt1, pc1The oil pressure of a certain moment gas well, pt1The casing pressure of a certain moment gas well; �� pf0Gas well with the pressure drop of scrubbed gas production phase loss, i.e. proof wellhead oil casing pressure reduction, �� pf0=pc0-pt0, pc0Gas well with the oil pressure of scrubbed gas production phase, pt0Gas well is with the casing pressure of scrubbed gas production phase;
D) formula
pt3-pt2> 0
In formula: Pt2And Pt3Refer to the gas well formerly casing pressure data in latter two different time sections;
E) formula
qg-qg0> 0
This formula prerequisite is under the geostationary condition of static pressure Pr of stratum,
In formula: qgThe gas production rate in gas well a certain moment, qg0Relative to qgThe gas production rate of gas well at the end of a front complete discharge opeing;
F) formula
p1-p2> 0
In formula: P1And P2Refer to the gas well formerly pressure of the well head stream in latter two different time sections data;
The above formula a)-f) in when at least meeting any three, then determine that described gas well has pit shaft to amass liquid, continue to perform step 400, otherwise perform step 200.
2. autocontrol method according to claim 1, it is characterized in that, described step 200 gathers the gas production rate that the relevant parameter of gas well plug-ging is oil pressure, casing pressure and gas well, gather the described oil pressure of described gas well and described casing pressure parameter especially by pressure transmitter, gathered the gas production rate of described gas well by under meter.
3. autocontrol method according to claim 1, it is characterised in that, described step 400 is concrete to be performed according to the following steps:
Step 401, if described formula analysis result determines that described pit shaft amasss liquid, performs step 400, if described formula analysis result determines the not long-pending liquid of described pit shaft, performs described step 200;
Step 402, calculates the long-pending liquid measure of described pit shaft;
Step 403, according to the long-pending liquid measure of the described pit shaft calculated, control automatic fluid removing system determine to need filling except liquid dosage, and calculate the working time needing to start dispenser pump, thus described pit shaft inner product liquid carried out automatically except liquid.
4. autocontrol method according to claim 3, it is characterised in that, the long-pending liquid measure calculating described pit shaft in described step 402 is according to following formulae discovery:
In formula: Q2The long-pending liquid measure of pit shaft, CgThe isothermal compressibility of Sweet natural gas; H' finishing drilling mine shaft depth; The tubing depth of H lower going-into-well cylinder, the diameter of D pit shaft, �� pcThe difference of the casing pressure of pit shaft different time sections, the equivalent height of �� H' finishing drilling pit shaft inner product liquid, the equivalent height of �� H oil pipe inner product liquid.
5. autocontrol method according to claim 1-4 arbitrary claim, it is characterized in that, described autocontrol method also comprises step 100, described step 100 was implemented before described step 200, described step 100 is extract the basic parameter of gas well, and described basic parameter comprises tubing and casing size, gas relative density, finishing drilling mine shaft depth, the tubing depth of lower going-into-well cylinder and liquid-gas interface tension force.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201210348123.5A CN103670352B (en) | 2012-09-18 | 2012-09-18 | Automatic control method for removing accumulated liquid in gas well |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201210348123.5A CN103670352B (en) | 2012-09-18 | 2012-09-18 | Automatic control method for removing accumulated liquid in gas well |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN103670352A CN103670352A (en) | 2014-03-26 |
| CN103670352B true CN103670352B (en) | 2016-06-08 |
Family
ID=50309042
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201210348123.5A Active CN103670352B (en) | 2012-09-18 | 2012-09-18 | Automatic control method for removing accumulated liquid in gas well |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN103670352B (en) |
Families Citing this family (18)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN105089572B (en) * | 2014-05-14 | 2018-03-09 | 中国石油天然气股份有限公司 | Intelligent gas well adjusting production method and device |
| CN104533388A (en) * | 2014-12-23 | 2015-04-22 | 中国石油天然气股份有限公司 | Method for measuring critical liquid carrying flow of gas well |
| CN104612659B (en) * | 2015-02-10 | 2017-03-15 | 中国地质大学（武汉） | A kind of determination method of the critical liquid carry over of low gas liquid rate gas well |
| CN105134150A (en) * | 2015-10-21 | 2015-12-09 | 中国石油化工股份有限公司 | Automatic filling system for gas well defoamer |
| CN106917624A (en) * | 2015-12-25 | 2017-07-04 | 甘德顺 | Shaft bottom, the determination of gas pipeline hydrops amount, foaming agent supply control system and method |
| CN105649603A (en) * | 2015-12-31 | 2016-06-08 | 中国石油天然气股份有限公司 | Method for testing gas well shaft liquid accumulation amount in real time |
| CN105927195B (en) * | 2016-05-31 | 2018-03-30 | 刘尚军 | A kind of natural gas well intelligent dosing method and the system for realizing this method |
| CN106703747A (en) * | 2016-12-12 | 2017-05-24 | 中国石油天然气股份有限公司 | Remote automatic control digital needle valve device and method and application thereof |
| CN108225244B (en) * | 2017-12-29 | 2019-12-17 | 深圳市宏电技术股份有限公司 | Method and system for measuring deposition thickness |
| CN108763657A (en) * | 2018-05-04 | 2018-11-06 | 中国石油天然气集团有限公司 | Horizontal gas well continuously takes liquid critical flow and determines method and device |
| CN110163442A (en) * | 2019-05-27 | 2019-08-23 | 华北理工大学 | A kind of gas well plug-ging prediction technique based on integrated study |
| CN113323642B (en) * | 2020-02-28 | 2023-10-13 | 中国石油化工股份有限公司 | Gas well effusion on-line diagnosis and foam liquid discharge gas production intelligent injection method |
| CN111472733B (en) * | 2020-06-03 | 2022-07-05 | 中测测控(西安)研究院有限公司 | Intelligent intermittent drainage gas production system and control method thereof |
| CN113931621B (en) * | 2020-07-14 | 2023-08-22 | 中国石油天然气股份有限公司 | Method, device and storage medium for determining gas well hydrops information |
| CN113361066B (en) * | 2021-04-16 | 2022-09-09 | 中国海洋石油集团有限公司 | Accumulated liquid and accumulated liquid degree identification method |
| CN113338915B (en) * | 2021-07-13 | 2022-04-12 | 西南石油大学 | Method for judging whether gas well accumulates liquid and predicting liquid accumulation height |
| CN114996662B (en) * | 2022-08-08 | 2022-11-08 | 西南石油大学 | Method for determining plunger well shaft accumulated liquid amount |
| CN117569803B (en) * | 2024-01-19 | 2024-03-26 | 四川速聚智联科技有限公司 | Prediction method and system for automatic drug delivery drainage of natural gas well |
Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP0011430A1 (en) * | 1978-11-10 | 1980-05-28 | Ferakarn Limited | Improvements in waste gas recovery systems |
| US4391135A (en) * | 1980-04-14 | 1983-07-05 | Mobil Oil Corporation | Automatic liquid level monitor |
| CN101871344A (en) * | 2010-06-02 | 2010-10-27 | 中国石油天然气股份有限公司 | Weighing type gas well shaft liquid level position determination method |
| CN102162347A (en) * | 2011-02-28 | 2011-08-24 | 西南石油大学 | Injection device capable of adapting to low-temperature environment in foam drainage gas recovery |
| CN202338335U (en) * | 2011-12-06 | 2012-07-18 | 中国石油天然气股份有限公司 | Plunger underground running state tracking system for gas production |
-
2012
- 2012-09-18 CN CN201210348123.5A patent/CN103670352B/en active Active
Patent Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP0011430A1 (en) * | 1978-11-10 | 1980-05-28 | Ferakarn Limited | Improvements in waste gas recovery systems |
| US4391135A (en) * | 1980-04-14 | 1983-07-05 | Mobil Oil Corporation | Automatic liquid level monitor |
| CN101871344A (en) * | 2010-06-02 | 2010-10-27 | 中国石油天然气股份有限公司 | Weighing type gas well shaft liquid level position determination method |
| CN102162347A (en) * | 2011-02-28 | 2011-08-24 | 西南石油大学 | Injection device capable of adapting to low-temperature environment in foam drainage gas recovery |
| CN202338335U (en) * | 2011-12-06 | 2012-07-18 | 中国石油天然气股份有限公司 | Plunger underground running state tracking system for gas production |
Non-Patent Citations (6)
| Title |
|---|
| 康成瑞等.天然气井井筒积液预测方法解析.《新疆石油天然气》.2009,74-75、96页. * |
| 张文洪等.泡沫排水采气工艺在大牛地气田的试验效果分析.《油气井测试》.2005,42-44页. * |
| 张新庄等.泡沫排水采气工艺软件的编制及应用.《计算机与应用化学》.2010,775-779页. * |
| 徐文龙等.苏里格气田气井数字一体化管理技术.《天然气技术与经济》.2012,66-68页. * |
| 田伟等.气井泡沫排水智能加注装置.《石油机械》.2012,78-85页. * |
| 翟丽娜等.气井排水采气工程分析设计软件的研制及应用.《中国石油和化工》.2012,45-47页. * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN103670352A (en) | 2014-03-26 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN103670352B (en) | Automatic control method for removing accumulated liquid in gas well | |
| CN107977749A (en) | A kind of prediction analysis method of oilfield development indexes | |
| CN103867184A (en) | Gas well critical liquid carrying flow determining method and device | |
| CN107843513A (en) | Analogue system and its emulation test method are evaluated in the screen cutting of hydrate recovery well machinery | |
| CN108894282A (en) | City planting ductwork operational safety dynamic early-warning method | |
| CN106021659A (en) | Method for determining corrosion rate of natural gas injection and production well pipe column under erosion-carbon dioxide corrosion coupling effect | |
| CN109241627A (en) | The dynamic shoring method of probability hierarchical and the device of Automated Design supporting scheme | |
| CN109236273B (en) | Dynamic data processing method for oil field development and production | |
| CN104975827B (en) | Predict the material balance method of carbon dioxide flooding oil reservoir index | |
| CN113343558A (en) | Drilling parameter optimization method based on fuzzy neural network | |
| CN106121622A (en) | A kind of Multiple faults diagnosis approach of Dlagnosis of Sucker Rod Pumping Well based on indicator card | |
| CN104405374A (en) | Method for measuring stress sensitivity of tight gas reservoir | |
| US8311743B2 (en) | Method for generating an estimation of incremental recovery from a selected enhanced oil recovery (EOR) process | |
| CN105822264A (en) | Method for detecting hydrate dynamic decomposition position of natural gas hydrate reservoir drilling well shaft | |
| CN106593415A (en) | Oil well dynamic liquid surface metering method based on improved multiphase flow algorithm | |
| CN114971338A (en) | Method for evaluating suitability of pumped storage power station for construction of mine subsidence area and roadway group | |
| CN109559017A (en) | Technical index limit before foam drainage gas production implementation of gas well in Qinghai gas area and determination of technical index limit | |
| CN107339096A (en) | Rapid water exploration method for horizontal well | |
| CN102606120B (en) | Steam flooding injection and production scheme determining method based on stochastic disturbance particle swarm optimization | |
| CN115248905A (en) | Method and device for calculating water folding coefficient by electric folding | |
| CN111946321B (en) | Proppant parameter design method for sand-filling temporary plugging fracturing | |
| CN110067555A (en) | Method and device for determining minimum dynamic reserve of carbonate oil well | |
| CN102878431B (en) | On-line monitoring method for flow pattern of multi-phase flow in oil and gas pipeline of offshore oilfield | |
| CN110500096B (en) | Method for determining production scale of hard rock type uranium mine | |
| CN116084921A (en) | Working fluid level prediction method, device, apparatus, and readable storage medium |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| C14 | Grant of patent or utility model | ||
| GR01 | Patent grant |