CN102536211A - Method for measuring and calculating liquid outlet temperature of well mouth of pumping unit well - Google Patents
Method for measuring and calculating liquid outlet temperature of well mouth of pumping unit well Download PDFInfo
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- CN102536211A CN102536211A CN2011103411793A CN201110341179A CN102536211A CN 102536211 A CN102536211 A CN 102536211A CN 2011103411793 A CN2011103411793 A CN 2011103411793A CN 201110341179 A CN201110341179 A CN 201110341179A CN 102536211 A CN102536211 A CN 102536211A
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- 239000007788 liquid Substances 0.000 title claims abstract description 30
- 238000000034 method Methods 0.000 title claims abstract description 21
- 238000005086 pumping Methods 0.000 title abstract description 7
- 239000003129 oil well Substances 0.000 claims abstract description 32
- 239000012530 fluid Substances 0.000 claims abstract description 24
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 21
- 238000005259 measurement Methods 0.000 claims description 18
- 230000008569 process Effects 0.000 abstract description 3
- 239000003208 petroleum Substances 0.000 abstract description 2
- 238000004364 calculation method Methods 0.000 abstract 1
- 230000008030 elimination Effects 0.000 abstract 1
- 238000003379 elimination reaction Methods 0.000 abstract 1
- 238000000691 measurement method Methods 0.000 abstract 1
- 230000002265 prevention Effects 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 29
- 239000010779 crude oil Substances 0.000 description 9
- 238000004519 manufacturing process Methods 0.000 description 5
- 238000004458 analytical method Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 239000012188 paraffin wax Substances 0.000 description 2
- 230000009467 reduction Effects 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- 230000008901 benefit Effects 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 230000002596 correlated effect Effects 0.000 description 1
- 230000000875 corresponding effect Effects 0.000 description 1
- 230000002354 daily effect Effects 0.000 description 1
- 238000009795 derivation Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000003203 everyday effect Effects 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
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- 238000011160 research Methods 0.000 description 1
- 238000005070 sampling Methods 0.000 description 1
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Abstract
The invention relates to the technical field of petroleum exploitation, in particular to a method for measuring and calculating the liquid outlet temperature of a well mouth of a pumping unit well, which aims to solve the problem of incapability of accurately calculating the liquid outlet temperature of the well mouth of the pumping unit well by the conventional measurement and calculation method. In order to solve the problem, the method for measuring and calculating the liquid outlet temperature of the well mouth of the pumping unit well is provided. The method comprises the following steps of: acquiring the liquid yield of an oil well; acquiring the moisture content of the oil well; measuring the depth of a working fluid level; acquiring a geothermal gradient; measuring the depth of an oil layer; calculating expansion power of solution gas; and calculating the liquid outlet temperature of the well mouth of the pumping unit well according to the parameters. By the method, influences on specific factors/variables of the liquid outlet temperature of the well mouth are reflected accurately, so that the liquid outlet temperature of the well mouth of the pumping unit well can be calculated accurately; and therefore, a good foundation is laid on operation processes of grasping temperature variation and viscosity variation in a well bore of the oil well, acquiring wax elimination and prevention rules of the oil well, determining collection and transportation modes and the like.
Description
Technical field
The present invention relates to technical field of petroleum extraction, specifically is a kind of well head fluid method of temperature of calculating rod-pumped well.
Background technology
It is an important parameter in the Process of Oil Pumping Unit Well that the well head of rod-pumped well goes out liquid temp; This Determination of Parameters changes variations in temperature, viscosity in the grasp well wellbore, to understanding the control and remove of well paraffin rule and failing the significant and effects in aspect such as mode at decision oil well collection.Present obtaining mainly through particular well is carried out in-site measurement of this parameter, and can't grasp its Changing Pattern.
Summary of the invention
The present invention is intended to address the above problem.Particularly; In the deep well pump manufacturing process; Influencing well head, to go out the factor of liquid temp a lot; But the inventor finds that through analysis and research major influence factors comprises reservoir temperature, surface temperature, production fluid amount, moisture content, dynamic oil level, crude oil saturation pressure, well head oil pressure, initial gas-oil ratio, the solubility factor of solution gas in crude oil etc.On this basis; Through testing repeatedly and mathematical modeling; The inventor confirms that further the variable that directly influences well head fluid temperature level specifically comprises: oilwell produced fluid amount, water ratio in oil well, dynamic oil level, geothermal gradient, reservoir depth and solution gas expansion power.
Specifically, for addressing the above problem, the present invention provides a kind of well head fluid method of temperature of calculating rod-pumped well, and this method comprises the following steps: to obtain oilwell produced fluid amount; Obtain water ratio in oil well; Measure dynamic oil level; Obtain geothermal gradient; Measure reservoir depth; Calculate solution gas expansion power; And according to said oilwell produced fluid amount, said water ratio in oil well, said dynamic oil level, said geothermal gradient, said reservoir depth and said solution gas expansion power, the well head that calculates said rod-pumped well goes out liquid temp.
What those skilled in the art knew is, oilwell produced fluid amount means the weight (unit is i.e. ton/sky of t/d-) of the crude oil that particular well produces every day, and it can pass through the situ metrology acquisition.Water ratio in oil well means the ratio of volume of volume and the output liquid (being crude oil) of particular well output water, representes that with percentage this parameter can obtain through field sampling and Measurement and analysis.Fathoming between the crude oil liquid level in well head to tubing and casing annular space when dynamic oil level means the rod-pumped well ordinary production, this parameter measures through ES Echo sounding usually.Reservoir depth means the oil reservoir vertical depth that measures through well logging.Geothermal gradient is claimed " geothermic gradient " again; It is the parameter of earth interior non-uniform temperature distributed degrees; The general buried depth temperature value of depths more is high more, shows that with a ℃ numerical table that increases on per hundred meters vertical depths it can calculate through the reservoir temperature of measuring oil well place block.Particularly, G geothermal gradient=100* (reservoir temperature-surface temperature)/reservoir depth.And the definition of solution gas expansion power is following: in crude oil lifting process, the solution gas in the crude oil is constantly separated out from crude oil because of the reduction of pressure, is converted into gaseous state from liquid state, and this causes the energy of material itself to reduce on the one hand, promptly interior can the reduction; On the other hand, this part energy changes into volume expansion ability (power) and acts on hoisting system, and this volume expansion power is known as solution gas expansion power.In the present invention, the interior essence that can reduce is that temperature reduces, and expansion power causes that temperature reduces in the oil pipe, directly influences the size that well head goes out liquid temp.More particularly, can come minute situation to calculate solution gas expansion power according to following formula:
In above-mentioned formula, P
SwollenBe solution gas expansion power, Q
oBe daily oil production (t/d), P
bBe crude oil saturation pressure (Mpa) that α is solubility factor (m
3/ (m
3.Mpa)), P
sBe pump intake pressure (Mpa), P
wBe well head oil pressure (Mpa).
In a preferred embodiment, can go out liquid temp according to the well head that formula is calculated rod-pumped well:
Wherein, T
MouthfulBe that well head goes out liquid temp, G is a geothermal gradient, Q
LiquidBe oilwell produced fluid amount, F
wBe water ratio in oil well, H
MovingBe dynamic oil level, H
OilBe reservoir depth, C
WaterBe that specific heat of water holds C
OilBe the specific heat capacity of oil, K
1Be the actual measurement coefficient, K
2Be the actual measurement coefficient, K
3Be the actual measurement coefficient, P
SwollenBe solution gas expansion power, and C is the actual measurement constant.In above-mentioned well head fluid temperature computation formula, C
WaterAnd C
OilBe known constant, G geothermal gradient, Q
LiquidOilwell produced fluid amount, F
wWater ratio in oil well, H
MovingDynamic oil level, H
OilReservoir depth and P
SwollenSolution gas expansion power all can obtain through mode mentioned above and other any suitable modes.About the actual measurement COEFFICIENT K
1, K
2, K
3And the actual measurement constant C, to different oil fields, at C
Water, C
Oil,Under the known situation of G, K
1, K
2, K
3, C can have different T through measuring at least 4 mouthfuls
Well head, Q
Liquid, Fw, H
Oil, H
Moving, P
SwollenRod-pumped well set up that equation is asked for or match, it is many more to measure the well number during match, the model that then simulates is accurate more.
Correspondingly; Said method of the present invention and formula have not only accurately reflected influences material elements/variable that well head goes out liquid temp; But also specifically confirmed the operation relation between these factor/variablees and the well head fluid temperature value; The well head that therefore can calculate rod-pumped well exactly goes out liquid temp, thereby lays a good foundation for grasping operations such as variations in temperature in the well wellbore, viscosity variation, understanding control and remove of well paraffin rule and the defeated mode of decision oil well collection.
Description of drawings
Describe preferred implementation of the present invention in conjunction with the drawings, those skilled in the art can understand above-mentioned and other feature and advantage of the present invention more fully, in the accompanying drawing:
Fig. 1 is the flow chart according to a preferred implementation of measuring method of the present invention.
The specific embodiment
Hereinafter only is exemplary to the description of preferred implementation of the present invention in essence, is not to be intended to limit invention, its application, or uses.Should be noted that; Although this preferred implementation has disclosed various concrete parameter of the present invention and details; But protection scope of the present invention is not limited to these parameters and details; Under the situation that does not depart from basic principle of the present invention, those skilled in the art can make modification, adjust or be equal to replacement to these parameters and details, for example can different order carry out each step in the said method.In addition; In order to practice thrift length; The application is not described in detail the derivation and the calculating of each related parameter, therefore, and when the obtain manner of certain or some parameters not being described in detail among the application; Will be understood that said parameter is well known to those skilled in the art and can obtains through methods known in the art, for example reservoir depth, dynamic oil level, all temps, various actual measurement coefficient and actual measurement constant etc.
As shown in Figure 1, the well head fluid method of temperature of measuring and calculating rod-pumped well of the present invention comprises the following steps: to obtain oilwell produced fluid amount; Obtain water ratio in oil well; Measure dynamic oil level; Obtain geothermal gradient; Measure reservoir depth; Calculate solution gas expansion power; And according to said oilwell produced fluid amount, said water ratio in oil well, said dynamic oil level, said geothermal gradient, said reservoir depth and said solution gas expansion power, the well head that calculates said rod-pumped well goes out liquid temp.
Further, on the basis of said method, the inventor is through a large amount of experiments and mathematical modeling repeatedly, and the well head that draws down the column count rod-pumped well goes out the formula of liquid temp:
In above-mentioned formula (the parenthetic of back is the conventional unit of corresponding factor/variable):
T
Well headFor wellhead production temperature (℃);
G is geothermal gradient (℃/100);
Q
LiquidBe oilwell produced fluid amount (m
3/ d);
F
wBe water ratio in oil well (%);
H
MovingBe dynamic oil level (m);
H
OilBe reservoir depth (m);
C
WaterFor specific heat of water holds (J/Kg);
C
OilSpecific heat capacity (J/Kg) for oil;
K
1Be the actual measurement coefficient;
K
2Be the actual measurement coefficient;
K
3Be the actual measurement coefficient;
C is the actual measurement constant.
In order to verify the accuracy of above-mentioned formula, the inventor tests under various different operating modes to 23 mouthfuls of oil wells, and will survey that well head goes out liquid temp and the well head fluid temperature value that calculates through above-mentioned formula compares, and correlated results sees also following table:
Can find out that through last table the measured value after the match and the index of correlation of calculated value are 0.9755, show that design formulas of the present invention can use.And measured value and the maximum absolute error between the calculated value in the last table are about 1.7 ℃, and relative error is about 4%.This shows; No matter the actual condition of particular well how; Measuring method/formula of the present invention all can calculate well head fluid temperature value exactly, therefore can lay a good foundation for the measuring and calculating and the improvement of other related system indexs such as down-hole viscous loss power and computer collecting system efficient.
Although described technical scheme of the present invention with reference to preferred implementation; But those skilled in the art are understood that easily; Protection scope of the present invention is not limited to these preferred implementations; Under the situation that does not depart from basic principle of the present invention, can to said embodiment and concrete technical characterictic wherein-for example each calculating/measuring and calculating step splits, makes up or changes, split, combination or change after technical scheme will fall within protection scope of the present invention.
Claims (2)
1. a well head fluid method of temperature of calculating rod-pumped well is characterized in that comprising the following steps:
Obtain oilwell produced fluid amount;
Obtain water ratio in oil well;
Measure dynamic oil level;
Obtain geothermal gradient;
Measure reservoir depth;
Calculate solution gas expansion power; And
According to said oilwell produced fluid amount, said water ratio in oil well, said dynamic oil level, said geothermal gradient, said reservoir depth and said solution gas expansion power, the well head that calculates said rod-pumped well goes out liquid temp.
2. the method for claim 1 is characterized in that, the well head that calculates said rod-pumped well according to formula goes out liquid temp:
Wherein, T
MouthfulBe that well head goes out liquid temp, G is a geothermal gradient, Q
LiquidBe oilwell produced fluid amount, F
wBe water ratio in oil well, H
MovingBe dynamic oil level, H
OilBe reservoir depth, C
WaterBe that specific heat of water holds C
OilBe the specific heat capacity of oil, K
1Be the actual measurement coefficient, K
2Be the actual measurement coefficient, K
3Be the actual measurement coefficient, P
SwollenBe solution gas expansion power, and C is the actual measurement constant.
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| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN2011103411793A CN102536211A (en) | 2011-11-02 | 2011-11-02 | Method for measuring and calculating liquid outlet temperature of well mouth of pumping unit well |
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|---|---|---|---|
| CN2011103411793A CN102536211A (en) | 2011-11-02 | 2011-11-02 | Method for measuring and calculating liquid outlet temperature of well mouth of pumping unit well |
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Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110067546A (en) * | 2019-04-15 | 2019-07-30 | 中国石油化工股份有限公司 | The method of discrimination of oil well channeling in steam-drive process |
Citations (4)
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|---|---|---|---|---|
| CN1245243A (en) * | 1999-07-15 | 2000-02-23 | 江苏石油勘探局石油工程技术研究院 | Method for designing parameters of mechanical oil extraction process of sucker-rod pump |
| CN2639512Y (en) * | 2003-09-04 | 2004-09-08 | 大庆油田有限责任公司 | Temp. control flushing apparatus capable of annulus logging well temp of flow flow pressure pumping well |
| CN1970991A (en) * | 2006-12-06 | 2007-05-30 | 中国石油大学(北京) | Method for metering oil production yield and analyzing and optimizing operating condition of oil well and system thereof |
| CN102168551A (en) * | 2011-01-19 | 2011-08-31 | 杨平 | Device and method for continuously measuring working fluid level depth of oil well and continuously metering produced liquid |
-
2011
- 2011-11-02 CN CN2011103411793A patent/CN102536211A/en active Pending
Patent Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN1245243A (en) * | 1999-07-15 | 2000-02-23 | 江苏石油勘探局石油工程技术研究院 | Method for designing parameters of mechanical oil extraction process of sucker-rod pump |
| CN2639512Y (en) * | 2003-09-04 | 2004-09-08 | 大庆油田有限责任公司 | Temp. control flushing apparatus capable of annulus logging well temp of flow flow pressure pumping well |
| CN1970991A (en) * | 2006-12-06 | 2007-05-30 | 中国石油大学(北京) | Method for metering oil production yield and analyzing and optimizing operating condition of oil well and system thereof |
| CN102168551A (en) * | 2011-01-19 | 2011-08-31 | 杨平 | Device and method for continuously measuring working fluid level depth of oil well and continuously metering produced liquid |
Non-Patent Citations (1)
| Title |
|---|
| 郑海金等: "能耗最低机采系统设计方法的研究及应用", 《石油学报》 * |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110067546A (en) * | 2019-04-15 | 2019-07-30 | 中国石油化工股份有限公司 | The method of discrimination of oil well channeling in steam-drive process |
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Application publication date: 20120704 |