CN114996662B - Method for determining plunger well shaft accumulated liquid amount - Google Patents
Method for determining plunger well shaft accumulated liquid amount Download PDFInfo
- Publication number
- CN114996662B CN114996662B CN202210942165.5A CN202210942165A CN114996662B CN 114996662 B CN114996662 B CN 114996662B CN 202210942165 A CN202210942165 A CN 202210942165A CN 114996662 B CN114996662 B CN 114996662B
- Authority
- CN
- China
- Prior art keywords
- shut
- well
- liquid
- oil pipe
- height
- 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
Images
Classifications
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F17/00—Digital computing or data processing equipment or methods, specially adapted for specific functions
- G06F17/10—Complex mathematical operations
- G06F17/18—Complex mathematical operations for evaluating statistical data, e.g. average values, frequency distributions, probability functions, regression analysis
-
- 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
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
Abstract
The invention discloses a method for determining the amount of accumulated liquid in a plunger well shaft, belonging to the technical field of oil and gas field development; the method aims to solve the problems that the existing determination method of the plunger well shaft effusion quantity is few in research, and the conventional method has great limitation; the technical scheme is as follows: collecting well body structure data of a gas well and gas well pressure data at a well closing critical moment; calculating the height of accumulated liquid in the annular space between the oil pipe and the sleeve; the equation of three unknowns related to the amount of liquid in the well bore is: the shut-in shaft liquid accumulation amount is equal to the sum of the shut-in oil pipe liquid accumulation amount and the shut-in casing pipe liquid accumulation amount, so that the shaft liquid accumulation amount can be determined by combining the equation relation of three unknown quantities related to the shut-in shaft liquid accumulation amount according to the calculated liquid accumulation heights in the oil pipe and the casing pipe. The method is simple and convenient to calculate, accurate in result and strong in applicability.
Description
Technical Field
The invention relates to a method for determining the amount of accumulated liquid in a plunger well shaft, and belongs to the technical field of oil and gas field development.
Background
With the development of a gas field, the formation pressure can be attenuated continuously, the formation produced water cannot be discharged in time, and accumulated at the bottom of the well to cause accumulated liquid, so that certain water and gas drainage measures are required to be taken to maintain the production of the gas well in the middle and later stages of the gas field development to avoid the early flooding of the gas well, and the service life of the gas well is prolonged. The plunger gas lift process is used as an important means for drainage and gas recovery in the middle and later periods of a gas well, is widely applied due to the characteristics of convenience and rapidness in operation, low cost, good adaptability, high automation degree and the like, can determine the effect of the plunger drainage and gas recovery process through the change of the liquid deposition at the bottom of the gas well in the process operation process, and is an important index except gas production rate and pressure.
After extensive research, the bottom liquid accumulation amount of the conventional liquid accumulation gas well is determined more at present, and the research on the determination method of the bottom liquid accumulation amount of the plunger well is less. The conventional testing method, the yield comparison method and the oil casing pressure difference prediction method are provided in the article Sulyge gas field underground throttle gas well accumulated liquid quantity prediction method and application to determine the well bottom accumulated liquid quantity, but the conventional shaft accumulated liquid testing cost is high, the calculation accuracy is different from well to well, and the popularization difficulty is high. An article, namely 'research on calculation methods of accumulated liquid in gas well shafts', establishes a calculation method of accumulated liquid in a gas well based on pressure and yield by analyzing pressure data in the production process of the gas well, but plunger well oil pressure and casing pressure fluctuation are large, and the method is used for calculating the accumulated liquid in the bottom of the plunger well with large possible errors.
In general, current research on methods for determining the amount of fluid in a wellbore of a plunger well is rare and there are major limitations to using conventional methods. Therefore, a method for determining the amount of accumulated liquid in the plunger well shaft with high operability and high accuracy is urgently needed to guide the efficient production of the plunger well.
Disclosure of Invention
The purpose of the invention is: in order to solve the problems that the existing determination method of the plunger well shaft accumulated liquid amount is few in research and has larger limitation by using a conventional method, the shaft accumulated liquid amount is determined by considering the structure and the pressure data of the plunger well shaft, the calculation is simple and convenient, the result is more accurate, the adaptability to the condition that the differential pressure of an oil sleeve slightly fluctuates during the production of a plunger production well is stronger, the actual shaft accumulated liquid amount of a gas well can be well reflected, and the precision is higher.
In order to achieve the above object, the present invention provides a method for determining the amount of liquid accumulated in a well bore of a plunger well, the method comprising the following steps:
the method comprises the steps of firstly, collecting well body structure data of a gas well and gas well pressure data at a well closing critical moment, wherein the well body structure data of the gas well comprises the lowering depth of a clamping device, the vertical depth of an oil pipe shoe, the inner diameter of a sleeve and the inner diameter of an oil pipe, and the gas well pressure data at the well closing critical moment comprises the oil pressure and the casing pressure at the moment;
secondly, calculating the height of accumulated liquid in the annular space between the oil pipe and the casing;
thirdly, determining the shaft liquid volume according to the liquid accumulation height in the oil pipe and the casing calculated in the second step by combining the equation relation of three unknown quantities related to the liquid accumulation volume of the shaft, wherein the equation relation of the three unknown quantities related to the shaft liquid volume is as follows: the shut-in shaft accumulated liquid amount is equal to the shut-in oil pipe accumulated liquid amount plus the shut-in casing accumulated liquid amount;
according to the method for determining the accumulated liquid amount of the shaft of the plunger well, the critical moment of closing the well is defined as the last moment of the well closing stage in the lifting period of the plunger, and the next moment enters the well opening stage;
the method for determining the accumulated liquid amount of the plunger well shaft comprises the specific steps of calculating the height of the accumulated liquid in the annular space between the oil pipe and the casing,
firstly, calculating the maximum value and the minimum value of the height difference between an oil pipe and casing liquid accumulation, wherein the maximum value is the ratio of the well bore liquid accumulation to the oil pipe sectional area, and the minimum value is 0;
secondly, setting a cycle counter, wherein the initial value of the cycle counter is 0;
thirdly, calculating a difference item and a current circulating effusion height difference, wherein the difference item is equal to a half of the difference between the maximum value and the minimum value of the current effusion height difference, and the current circulating effusion height difference is the sum of the minimum value of the effusion height difference and the difference item;
fourth, updating the cycle counter, which is the value of the previous counter plus 1;
fifthly, calculating the bottom hole flowing pressure error, which comprises the following steps,
the method comprises the following steps of firstly, converting oil pressure and casing pressure at a critical moment of closing a well into bottom hole flowing pressure, wherein the expression is as follows:
in the formula p t_shut The unit is the oil pressure at the critical moment of closing the well and is MPa; gamma ray g The relative density of natural gas is zero dimension, and methane is 0.56; h g_tube_shut The height of the gas column is the height of the gas column of the oil taking pipe0.5 times the degree in m;
taking one half of the sum of the wellhead temperature and the formation temperature as the average temperature of the system, wherein the unit is K;
is a system average deviation factor without factors; the "-" above T and Z represents an average value; rho w Is the liquid density in kg/m 3 (ii) a g is gravity acceleration, and is 9.8m/s 2 ；p c_shut The unit is the casing pressure at the critical moment of closing the well, and is MPa; h g_hk_shut The height of the air column is 0.5 times of the height of the air column, and the unit is m.
Secondly, calculating a bottom hole flowing pressure error according to the converted bottom hole flowing pressure, wherein the expression is as follows:
wherein err is the bottom hole flow pressure error; p is a radical of wf_hk_shut The unit of the bottom hole flowing pressure obtained by sleeve pressure conversion at the well closing critical moment is MPa; p is a radical of wf_tube_shut The unit of the bottom hole flowing pressure obtained by converting the oil pressure at the well closing critical moment is MPa;
sixthly, when the error of the bottom hole flow pressure obtained by calculation is less than 0.001, finishing the calculation, otherwise, comparing p wf_hk_shut And p wf_tube_shut When p is the size of wf_hk_shut ＞p wf_tube_shut When the liquid level difference between the oil pipe and the casing pipe is equal to the current liquid level difference, when the liquid level difference is p wf_hk_shut ≤p wf_tube_shut In time, the maximum value of the height difference of the accumulated liquid of the oil pipe and the casing pipe is equal to the current height difference of the accumulated liquid, and the steps from the first step to the sixth step are repeated until the calculation is finished;
seventhly, obtaining the height of the accumulated liquid in the annular space between the oil pipe and the casing, wherein the expression is as follows:
in the formula H l_hk_shut The unit is m, which is the height of the effusion in the annular space of the sleeve; h l_tube_shut The unit is m, which is the height of accumulated liquid in the oil pipe; v w_shut The amount of accumulated fluid in the shut-in well bore is expressed in m 3 ；dH l_shut The height difference of accumulated liquid between the oil pipe and the casing pipe is m; a. The tube Is the cross section area of the oil pipe, and the unit is m 2 ；A hk Is the flow area inside the annulus, and has a value equal to the difference between the cross-sectional area of the casing and the cross-sectional area of the tubing, and has a unit of m 2 。
Drawings
FIG. 1 is a technical scheme of the present invention.
FIG. 2 is a diagram of gas-liquid distribution of a well bore of a plunger well at a critical moment of well shut-in.
FIG. 3 is a flow chart of calculation of the liquid level in the oil pipe and casing annulus.
FIG. 4 is a graph of plunger well bore fluid volume as a function of production time.
Detailed Description
The invention is further described below with reference to the accompanying drawings.
The invention provides a method for determining the passing size of a plunger in a continuous oil pipe, wherein FIG. 1 is a technical route chart of the method, FIG. 2 is a shaft gas-liquid distribution relation chart of a plunger well at a well closing critical moment, and the method comprises the following steps:
collecting well body structure data of a gas well and gas well pressure data at the critical closing time, wherein the well body structure data of the gas well comprises the lowering depth of a clamping device, the vertical depth of an oil pipe shoe, the inner diameter of a sleeve and the inner diameter of an oil pipe, and the gas well pressure data at the critical closing time comprises the oil pressure and the casing pressure at the time;
secondly, calculating the height of accumulated liquid in the annular space between the oil pipe and the casing;
thirdly, determining the shaft liquid volume according to the liquid accumulation height in the oil pipe and the casing calculated in the second step by combining the equation relation of three unknown quantities related to the liquid accumulation volume of the shaft, wherein the equation relation of the three unknown quantities related to the shaft liquid volume is as follows: the shut-in shaft accumulated liquid amount is equal to the shut-in oil pipe accumulated liquid amount plus the shut-in casing accumulated liquid amount;
further, in the method for determining the accumulated liquid amount of the shaft of the plunger well, the critical moment of closing the well is defined as the last moment of the well closing stage in the lifting cycle of the plunger, and the next moment enters the well opening stage;
further, the method for determining the amount of accumulated liquid in the shaft of the plunger well calculates the height of the accumulated liquid in the annular space between the oil pipe and the casing, fig. 3 is a flow chart for calculating the height of the accumulated liquid in the annular space between the oil pipe and the casing, and the specific steps are as follows,
firstly, calculating the maximum value and the minimum value of the height difference between an oil pipe and casing liquid accumulation, wherein the maximum value is the ratio of the well bore liquid accumulation to the oil pipe sectional area, and the minimum value is 0;
secondly, setting a cycle counter, wherein the initial value of the cycle counter is 0;
thirdly, calculating a difference item and the height difference of the effusion in the current cycle, wherein the difference item is equal to half of the difference between the maximum value and the minimum value of the height difference of the effusion in the current cycle, and the height difference of the effusion in the current cycle is the sum of the minimum value and the difference item of the height difference of the effusion in the current cycle;
fourth, updating the cycle counter, which is the value of the previous counter plus 1;
fifthly, calculating the bottom hole flowing pressure error, which comprises the following steps,
the method comprises the following steps of firstly, converting oil pressure and casing pressure at a critical moment of closing a well into bottom hole flowing pressure, wherein the expression is as follows:
in the formula p t_shut The unit is the oil pressure at the critical moment of well closing and is MPa; gamma ray g The relative density of natural gas is zero dimension, and methane is 0.56; h g_tube_shut Taking the height of the oil pipe as the height of the gas column, wherein the height of the oil pipe is 0.5 time of the height of the gas column, and the unit is m;
taking the sum of the wellhead temperature and the formation temperature as the average temperature of the systemOne-half of (a), unit is K;
the system average deviation factor is zero dimension; the "-" above T and Z represents an average value; ρ is a unit of a gradient w Is the liquid density in kg/m 3 (ii) a g is gravity acceleration, and is 9.8m/s 2 ；p c_shut The unit is the casing pressure at the critical moment of closing the well, and is MPa; h g_hk_shut The height of the air column is 0.5 times of the height of the air column, and the unit is m.
Secondly, calculating a bottom hole flowing pressure error according to the converted bottom hole flowing pressure, wherein the expression is as follows:
wherein err is the bottom hole flow pressure error; p is a radical of formula wf_hk_shut The bottom hole flowing pressure obtained by sleeve pressure conversion at the critical moment of closing the well is expressed in MPa; p is a radical of wf_tube_shut The unit of the bottom hole flowing pressure obtained by converting the oil pressure at the critical moment of closing the well is MPa;
sixthly, when the error of the bottom hole flow pressure obtained by calculation is less than 0.001, finishing the calculation, otherwise, comparing p wf_hk_shut And p wf_tube_shut When p is the size of wf_hk_shut ＞p wf_tube_shut When the liquid level difference between the oil pipe and the casing pipe is equal to the current liquid level difference, when the liquid level difference is p wf_hk_shut ≤p wf_tube_shut When the calculation is finished, the maximum value of the height difference of the effusion of the oil pipe and the casing is equal to the current height difference of the effusion, and the steps from the first step to the sixth step are repeated until the calculation is finished;
seventhly, obtaining the height of accumulated liquid in the annular space between the oil pipe and the sleeve, wherein the expressions are as follows:
in the formula H l_hk_shut The unit is m, which is the height of the effusion in the annular space of the sleeve; h l_tube_shut For high liquid loading in the oil pipeDegree, in m; v w_shut The amount of accumulated fluid in the shut-in well bore is expressed in m 3 ；dH l_shut The height difference of accumulated liquid between the oil pipe and the casing pipe is m; a. The tube Is the cross-sectional area of the oil pipe, and the unit is m 2 ；A hk Is the flow area inside the annulus, and has a value equal to the difference between the cross-sectional area of the casing and the cross-sectional area of the tubing, and has a unit of m 2 。
Further, the wellbore fluid volume is determined, and the obtained result is a graph of the plunger well wellbore fluid volume as a function of production time as shown in fig. 4.
Claims (2)
1. A method of determining the amount of liquid accumulated in a wellbore of a plunger well, the method comprising the steps of:
s100, collecting well body structure data of a gas well and gas well pressure data at a well closing critical moment, wherein the well body structure data of the gas well comprise a lowering depth of a clamping device, a vertical depth of an oil pipe shoe, a sleeve inner diameter and an oil pipe inner diameter, and the gas well pressure data at the well closing critical moment comprise oil pressure and casing pressure at the moment;
s200, calculating the height of accumulated liquid in the annular space between the oil pipe and the casing, which comprises the following specific steps,
s201, calculating the maximum value and the minimum value of the height difference between the oil pipe and the casing liquid accumulation, wherein the maximum value is the ratio of the well bore liquid accumulation to the oil pipe sectional area, and the minimum value is 0;
s202, setting a cycle counter, wherein the initial value of the cycle counter is 0;
s203, calculating a difference item and a current circulating effusion height difference, wherein the difference item is equal to a half of the difference between the maximum value and the minimum value of the current effusion height difference, and the current circulating effusion height difference is the sum of the minimum value of the effusion height difference and the difference item;
s204, updating a cycle counter, wherein the value of the cycle counter is the value of the previous counter plus 1;
s205, calculating a bottom hole flow pressure error, which comprises the following specific steps,
s2051, converting the oil pressure and the casing pressure at the critical moment of closing the well into bottom hole flowing pressure, wherein the expression is as follows:
in the formula p t_shut The unit is the oil pressure at the critical moment of closing the well and is MPa; gamma ray g The relative density of natural gas is zero dimension, and methane is 0.56; h g_tube_shut Taking the height of the oil pipe as the height of the gas column, wherein the height of the oil pipe is 0.5 time of the height of the gas column, and the unit is m;
taking one half of the sum of the wellhead temperature and the formation temperature as the average temperature of the system, wherein the unit is K;
the system average deviation factor is zero dimension; the "-" above T and Z represents an average value; rho w Is the liquid density in kg/m 3 (ii) a g is gravity acceleration, and is 9.8m/s 2 ；p c_shut The unit is the casing pressure at the critical moment of closing the well, and is MPa; h g_hk_shut Taking the height of the air column as 0.5 time, and the unit is m;
s2052, calculating a bottom hole flowing pressure error according to the converted bottom hole flowing pressure, wherein the expression is as follows:
wherein err is the bottom hole flow pressure error; p is a radical of wf_hk_shut The bottom hole flowing pressure obtained by sleeve pressure conversion at the critical moment of closing the well is expressed in MPa; p is a radical of wf_tube_shut The unit of the bottom hole flowing pressure obtained by converting the oil pressure at the well closing critical moment is MPa;
s206, when the error calculated in the step S205 is less than 0.001, finishing the calculation, otherwise, comparing p wf_hk_shut And p wf_tube_shut When p is the size of wf_hk_shut ＞p wf_tube_shut When the current liquid level difference is equal to the minimum value of the liquid level difference between the oil pipe and the casing, when the current liquid level difference is p wf_hk_shut ≤p wf_tube_shut When it is needed, let oilThe maximum value of the height difference of the effusion of the pipe and the sleeve is equal to the height difference of the current effusion, and the steps S201 to S206 are repeated until the calculation is finished;
s207, obtaining the height of accumulated liquid in the annular space between the oil pipe and the casing, wherein the expressions are as follows:
in the formula H l_hk_shut The unit is m, which is the height of the effusion in the annular space of the sleeve; h l_tube_shut The unit is m, which is the height of accumulated liquid in the oil pipe; v w_shut The amount of accumulated fluid in the shut-in wellbore is m 3 ；dH l_shut The height difference of accumulated liquid between the oil pipe and the casing pipe is m; a. The tube Is the cross-sectional area of the oil pipe, and the unit is m 2 ；A hk Is the flow area inside the annulus, and the value is equal to the difference between the cross section area of the casing and the cross section area of the oil pipe, and the unit is m 2 ；
S300, determining the shaft liquid volume according to the liquid accumulation height in the oil pipe and the casing calculated in the step S200 by combining the equation relation of three unknown quantities related to the liquid accumulation volume of the shaft, wherein the equation relation of the three unknown quantities related to the shaft liquid volume is as follows: the shut-in shaft accumulated liquid amount is equal to the shut-in oil pipe accumulated liquid amount plus the shut-in casing accumulated liquid amount.
2. The method for determining the liquid loading amount in the shaft of the plunger well according to claim 1, wherein the method comprises the following steps: the critical moment of closing the well is defined as the last moment of the well closing stage in the lifting cycle of the plunger, and the next moment enters the well opening stage.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202210942165.5A CN114996662B (en) | 2022-08-08 | 2022-08-08 | Method for determining plunger well shaft accumulated liquid amount |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202210942165.5A CN114996662B (en) | 2022-08-08 | 2022-08-08 | Method for determining plunger well shaft accumulated liquid amount |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN114996662A CN114996662A (en) | 2022-09-02 |
| CN114996662B true CN114996662B (en) | 2022-11-08 |
Family
ID=83023016
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202210942165.5A Active CN114996662B (en) | 2022-08-08 | 2022-08-08 | Method for determining plunger well shaft accumulated liquid amount |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN114996662B (en) |
Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103590812A (en) * | 2013-10-21 | 2014-02-19 | 中国石油天然气股份有限公司 | Calculating method, calculating device and determining method of gas well effusion volume |
| CN103670352A (en) * | 2012-09-18 | 2014-03-26 | 中国石油天然气股份有限公司 | Automatic control method for removal of gas well deposition liquid |
| CN104504611A (en) * | 2014-12-11 | 2015-04-08 | 中国石油天然气股份有限公司 | Method for determining whether liquid accumulation exists in gas well or not and determining liquid accumulation degree |
| CN105649603A (en) * | 2015-12-31 | 2016-06-08 | 中国石油天然气股份有限公司 | Method for measuring accumulated liquid quantity of well bore of gas well in real time |
| CN111749654A (en) * | 2020-08-05 | 2020-10-09 | 西安众海石油科技有限公司 | Method and system for controlling gas well plunger gas lift drainage gas recovery |
| CN112800377A (en) * | 2021-01-05 | 2021-05-14 | 中国石油天然气股份有限公司 | Gas well shaft accumulated liquid amount calculation method, system, equipment and storage medium |
| CN114526056A (en) * | 2020-11-05 | 2022-05-24 | 中国石油化工股份有限公司 | Method for calculating height of accumulated liquid in shaft of underground throttling gas well |
Family Cites Families (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN104790916B (en) * | 2015-04-24 | 2017-04-19 | 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 | Method for removing gas well accumulated liquid by means of oil jacket pressure balancing 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 |
| CN113389525A (en) * | 2021-07-30 | 2021-09-14 | 中国石油化工股份有限公司 | Shale gas well foam exhausting-gas lifting composite process design method and process flow thereof |
| CN114861471B (en) * | 2022-07-06 | 2022-10-11 | 西南石油大学 | Method for determining application time of plunger gas lift process |
-
2022
- 2022-08-08 CN CN202210942165.5A patent/CN114996662B/en active Active
Patent Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103670352A (en) * | 2012-09-18 | 2014-03-26 | 中国石油天然气股份有限公司 | Automatic control method for removal of gas well deposition liquid |
| CN103590812A (en) * | 2013-10-21 | 2014-02-19 | 中国石油天然气股份有限公司 | Calculating method, calculating device and determining method of gas well effusion volume |
| CN104504611A (en) * | 2014-12-11 | 2015-04-08 | 中国石油天然气股份有限公司 | Method for determining whether liquid accumulation exists in gas well or not and determining liquid accumulation degree |
| CN105649603A (en) * | 2015-12-31 | 2016-06-08 | 中国石油天然气股份有限公司 | Method for measuring accumulated liquid quantity of well bore of gas well in real time |
| CN111749654A (en) * | 2020-08-05 | 2020-10-09 | 西安众海石油科技有限公司 | Method and system for controlling gas well plunger gas lift drainage gas recovery |
| CN114526056A (en) * | 2020-11-05 | 2022-05-24 | 中国石油化工股份有限公司 | Method for calculating height of accumulated liquid in shaft of underground throttling gas well |
| CN112800377A (en) * | 2021-01-05 | 2021-05-14 | 中国石油天然气股份有限公司 | Gas well shaft accumulated liquid amount calculation method, system, equipment and storage medium |
Non-Patent Citations (2)
| Title |
|---|
| 苏里格气井井筒积液量计算方法及应用;陈增辉 等;《石油化工应用》;20160831;第35卷(第8期);第25-27、35页 * |
| 黄雨 等.苏里格气田带节流器气井积液预测研究.《 2020油气田勘探与开发国际会议论文集》.2020, * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN114996662A (en) | 2022-09-02 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN107563899B (en) | Oil-gas well productivity prediction method and device | |
| CN104504604B (en) | A kind of method of qualitative Wellbore of Gas Wells hydrops | |
| CN107608940B (en) | Method for determining oil well interval pumping period | |
| US10208548B2 (en) | Method for detecting gain or loss of drilling fluid in a drilling installation associated calculation system and associated drilling installation | |
| CN101253402A (en) | Method for evaluating unsaturation coalbed gas storage layer | |
| CA2392618C (en) | Improved method and apparatus for predicting the fluid characteristics in a well hole | |
| CN110847894B (en) | Method for determining flow pressure of underground throttling gas well | |
| CN109815543A (en) | The method for calculating gas field dynamic holdup | |
| CN109958431A (en) | A method of oil well daily fluid production rate is calculated based on inflow performance relationship curve | |
| CN115408956A (en) | Method for acquiring periphysical and mechanical parameters of hydrate reservoir drilling well in real time | |
| CN114996662B (en) | Method for determining plunger well shaft accumulated liquid amount | |
| CN113338915B (en) | Method for judging whether gas well accumulates liquid and predicting liquid accumulation height | |
| RU2683435C1 (en) | Method for selecting the optimal operating mode of oil well | |
| CN113062733B (en) | Segmented horizontal well water control three-dimensional simulation experiment device and experiment method thereof | |
| CN113338916A (en) | Method for predicting and diagnosing shaft effusion | |
| CN114861471B (en) | Method for determining application time of plunger gas lift process | |
| CN113032987A (en) | Dynamic analysis method for gas invasion characteristic of drilling without marine riser | |
| RU2540720C1 (en) | Development of oil seam by horizontal well extensions | |
| CN109736772A (en) | It is a kind of to return out the simple pressure control drilling method monitored and system based on annular space | |
| CN114427444A (en) | Bottom hole pressure prediction method for oil production well in flowing period | |
| CN114526056A (en) | Method for calculating height of accumulated liquid in shaft of underground throttling gas well | |
| CN112709547A (en) | Method for judging water plugging time of water producing gas well | |
| RU2320855C1 (en) | Well operation device | |
| CN114060009B (en) | Downhole throttling natural gas well effusion judging method | |
| CN112267872B (en) | Method for determining volume of gas well drilling karst cave system by using production dynamic data |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| TA01 | Transfer of patent application right | ||
| TA01 | Transfer of patent application right |
Effective date of registration: 20221020 Address after: 610500, Xindu Avenue, Xindu District, Sichuan, Chengdu, 8 Applicant after: SOUTHWEST PETROLEUM University Address before: 610095 No. 7, 6th Floor, Block C, Building 7, Tianfu Xingu, No. 399, West Section of Fucheng Avenue, Wuhou District, Chengdu City, Sichuan Province Applicant before: Chengdu Yingwoxin Technology Co.,Ltd. |
|
| GR01 | Patent grant | ||
| GR01 | Patent grant |