CN110185434A - The fluid of oil gas water well injects or the measuring device and its method of output distribution flow - Google Patents
The fluid of oil gas water well injects or the measuring device and its method of output distribution flow Download PDFInfo
- Publication number
- CN110185434A CN110185434A CN201910433003.7A CN201910433003A CN110185434A CN 110185434 A CN110185434 A CN 110185434A CN 201910433003 A CN201910433003 A CN 201910433003A CN 110185434 A CN110185434 A CN 110185434A
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- 239000012530 fluid Substances 0.000 title claims abstract description 54
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 26
- 238000000034 method Methods 0.000 title claims abstract description 15
- 238000010438 heat treatment Methods 0.000 claims abstract description 74
- 239000002131 composite material Substances 0.000 claims abstract description 66
- 239000000835 fiber Substances 0.000 claims abstract description 54
- 239000013307 optical fiber Substances 0.000 claims abstract description 26
- 238000002347 injection Methods 0.000 claims abstract description 22
- 239000007924 injection Substances 0.000 claims abstract description 22
- 239000004020 conductor Substances 0.000 claims description 21
- 238000005259 measurement Methods 0.000 claims description 19
- 238000004519 manufacturing process Methods 0.000 claims description 12
- 238000000691 measurement method Methods 0.000 claims description 9
- XQCFHQBGMWUEMY-ZPUQHVIOSA-N Nitrovin Chemical compound C=1C=C([N+]([O-])=O)OC=1\C=C\C(=NNC(=N)N)\C=C\C1=CC=C([N+]([O-])=O)O1 XQCFHQBGMWUEMY-ZPUQHVIOSA-N 0.000 claims description 8
- 238000001514 detection method Methods 0.000 claims description 7
- 230000006641 stabilisation Effects 0.000 claims description 6
- 238000011105 stabilization Methods 0.000 claims description 6
- 229910001220 stainless steel Inorganic materials 0.000 claims description 5
- 239000010935 stainless steel Substances 0.000 claims description 5
- 238000004364 calculation method Methods 0.000 claims description 3
- 239000007788 liquid Substances 0.000 claims description 2
- 238000005485 electric heating Methods 0.000 abstract 1
- 239000007789 gas Substances 0.000 description 11
- 229910001006 Constantan Inorganic materials 0.000 description 7
- RYGMFSIKBFXOCR-UHFFFAOYSA-N Copper Chemical compound [Cu] RYGMFSIKBFXOCR-UHFFFAOYSA-N 0.000 description 7
- 229910052802 copper Inorganic materials 0.000 description 7
- 239000010949 copper Substances 0.000 description 7
- 238000005516 engineering process Methods 0.000 description 4
- 230000003287 optical effect Effects 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 239000004744 fabric Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012544 monitoring process Methods 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 206010037660 Pyrexia Diseases 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 239000003570 air Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 235000013399 edible fruits Nutrition 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000004134 energy conservation Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 230000000155 isotopic effect Effects 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000002343 natural gas well Substances 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/26—Storing data down-hole, e.g. in a memory or on a record carrier
Landscapes
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Physics & Mathematics (AREA)
- Mining & Mineral Resources (AREA)
- Geophysics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Remote Sensing (AREA)
- Measuring Volume Flow (AREA)
- Measuring Temperature Or Quantity Of Heat (AREA)
Abstract
The fluid of oil gas water well injects or output is distributed the measuring device of flow and its method belongs to the fluid injection of field of measuring techniques more particularly to a kind of oil gas water well or the measuring device and its method of output distribution flow.The fluid that the present invention provides a kind of oil gas water well injects or the measuring device and its method of output distribution flow.The fluid of oil gas water well of the present invention injects or the measuring device of output distribution flow includes optical fiber 5 and heating wires 6, and structural feature optical fiber 5 and 6 armouring of heating wires are composite cable 1.By, for electric heating, reading the fiber optic Distributed Temperature of each section of pit shaft of composite cable 1 to heating wires 6, the fluid flow of corresponding mine shaft depth is obtained.
Description
Technical field
The invention belongs to a kind of injections of the fluid of field of measuring techniques more particularly to oil gas water well or output to be distributed flow
Measuring device and its method.
Background technique
With the high speed development of new energy industry, the exploitation and production management of all kinds of clean energy resource wells are gradually to intelligence
Management development.Downhole flow measuring technology is the important component of all kinds of clean energy resource production technologies, it mainly by
Flow rate instrument is placed to fulfil assignment in underground.
Downhole flow measuring technology is mainly real-time acquisition, monitoring and the place solved in energy extraction to downhole flow data
The problem of reason, optimizes the yield of payzone, improves the purpose of yield to reach quickly modification production practice.
Conventional downhole flow measuring device mainly has turbine flowmeter, and full bore flowmeter, floats at afflux basket flowmeter
Subflow meter, ultrasonic flowmeter, isotopic tracing flow meter, electromagnetic flowmeter etc..These flowmeter technology relative maturities, measuring accuracy
It is higher, but its major defect is that measurement is long duty cycle, and ancillary equipment is complicated, investment is big, influences measurement accuracy vulnerable to hole condition.And
It is only applicable to individual well point type flow measurement, is not suitable for the distributed stream measurement of fluid, it is non-to be used as the permanently mounted rear calibration in underground
It is often difficult.
The content of present invention
The present invention addresses the above problem, and the fluid for providing a kind of oil gas water well injects or the measurement of output distribution flow
Devices and methods therefor.
To achieve the above object, the present invention adopts the following technical scheme that, the fluid injection of oil gas water well of the present invention or output
The measuring device of distribution flow includes optical fiber 5 and heating wires 6, and structural feature optical fiber 5 and 6 armouring of heating wires are complex light
Cable 1.
As a preferred embodiment, the heating power supply 2 of heating wires 6 of the present invention uses SDC1000 type DC power supply.
As another preferred embodiment, composite cable of the present invention is stainless steel tube armouring composite cable.
As another preferred embodiment, the detection signal input part of optical fiber 5 and fiber distribution temperature measuring equipment 3 of the present invention
Mouth is connected.
As another preferred embodiment, the signal output port and computer 4 of fiber distribution temperature measuring equipment 3 of the present invention
Detection signal input port be connected.
The fluid of oil gas water well of the present invention injects or the measurement method of output distribution flow are as follows: by optical fiber 5 and heating wires 6
Armouring is that composite cable 1 is vertically laid in pit shaft, and heating power supply 2 is powered heating wires 6, so that composite cable 1
Heating；
By the optical fiber in composite cable, the fiber optic Distributed Temperature of the touched fluid of composite cable 1 where measuring fluid；
Distributed fluid mass flow FiRelationship between fiber optic Distributed Temperature is as follows:
Wherein IiTo pass through 1 i-th section of composite cable of electric current；RiFor 1 i-th section of resistance of composite cable；TiFor composite cable
1 i-th section of heating temperature；TwFor the temperature before 1 i-th section of composite cable of heating；A, B are empirical.
As a preferred embodiment, heating wires 6 of the present invention are heated using full well section or part well section heats.
As a preferred embodiment, full well section heating of the present invention refers to: heating wires are a kind of conductor；Part well section
Heating refers to: heating wires are that two kinds of conductors are spliced.
As a preferred embodiment, a kind of conductor of the present invention refers to copper conductor or constantan conductor；It is described two to lead
Body refers to copper conductor and constantan conductor.
As another preferred embodiment, the present invention uses fiber distribution temperature measuring equipment 3 (DTS-8000), passes through composite cable
In optical fiber measurement fluid where the touched fluid of composite cable 1 fiber optic Distributed Temperature.
As another preferred embodiment, the present invention shows fiber optic Distributed Temperature on the computer 4, passes through fiber distribution thermometric
The fiber optic Distributed Temperature that device 3 measures calculates Distributed fluid mass flow.
As another preferred embodiment, A of the present invention, the method for determination of B empirical are as follows: by changing known well
The measurable injection of mouth fluid or output flow, due to heated current IiConstant and it is known that bringing-up section resistance RiIt is also known that logical
It crosses under two kinds of different well head flow values and corresponding current stabilization state under conditions of fiber optic Distributed Temperature value, obtains formula
About A is solved, B empirical equation with two unknowns derives the A that distribution flow is calculated under the conditions of current hole condition, B empirical.
Secondly, leading to after computer 4 of the present invention is not powered in heating power supply 2, and fluid flows current stabilization in the wellbore
It crosses the measurement of fiber distribution temperature measuring equipment 3 and obtains the districution temperature value T of composite cable 1w(w=1,2 ..., n), n is optical fiber point
Total number of segment of cloth temperature；
The computer 4 controls heating power supply 2 and carries out constant current I to the heating wires 6 in composite cable 1iPower supply, according to light
The 1 stranding parameter of spatial resolution and composite cable of fibre distribution temperature measuring equipment 3, RiIt is known；Wherein supply current IiSize
When with pit shaft maximum flow, can generate subject to the temperature change that fiber distribution temperature measuring equipment 3 can identify (such as maximum stream flow
When, temperature can heat up 5 DEG C or more)；After fiber optic Distributed Temperature thermal field is stablized, measured by fiber distribution temperature measuring equipment 3
To the districution temperature value T of composite cablei(i=1,2 ..., n), n is total number of segment of fiber optic Distributed Temperature.
By calculation formula (3), successively calculates and be distributed the corresponding fluid mass stream of thermometric section in 1 bringing-up section of composite cable
Measure Fi(i=1,2 ..., n), n is total distribution flow number.
In addition, the present invention is knowing well head total flow FallUnder the premise of, and injection or the production profile of the payzone calculated
With well head total flow FallWhen not being inconsistent, it is corrected by following formula；
Wherein PiFor the flow of the i-th output layer, FiIt is the i-th calculated flow of output layer, FjIt is that jth output layer calculates
Flow, m be payzone sum.
Beneficial effect of the present invention.
The configuration of the present invention is simple, working range wide (armouring composite cable can be used under high temperature, condition of high voltage), each section of stream
Comparison of coherence between amount good (measurement of distribution flow being carried out using optical fiber 5, comparison of coherence is good), can be in real time under production wells
Data on flows is particularly suitable for that permanent monitoring is fixedly mounted, it is more stable to be suitable for SPECIFIC HEAT CAPACITY, it can be achieved that the continuous measurement of distribution
Medium, such as water injection well, geothermal well, the natural gas well etc..
Detailed description of the invention
The present invention will be further described with reference to the accompanying drawings and detailed description.The scope of the present invention not only limits to
In the statement of the following contents.
Fig. 1 is the system structure diagram that the present invention is used for gas production flow measurement.
Specific embodiment
As shown, the fluid injection of oil gas water well of the present invention or the measuring device of output distribution flow include 5 He of optical fiber
Heating wires 6, optical fiber 5 and 6 armouring of heating wires are composite cable 1.
The heating power supply 2 of the heating wires 6 uses SDC1000 type DC power supply.Heating wires 6 are in composite cable 1
Set-up mode be lower end connection two vertical lines, the upper ends of two vertical lines is the both ends of heating wires 6, the two of heating wires 6
End is connected with DC power supply positive and negative anodes.Set-up mode of the optical fiber 5 in composite cable 1 is one corresponding with two vertical lines perpendicular
Line, the vertical line upper end are connected with the detection signal input port of fiber distribution temperature measuring equipment 3.
The composite cable is stainless steel tube armouring composite cable (as shown in Figure 1, optical fiber 5 and heating wires 6 are placed in
Composite cable 1 is formed in stainless steel tube).Due to using stainless steel tube armouring composite cable, it is more applicable for that corrosivity is strong, electromagnetism
Interfere the adverse circumstances such as big.
The optical fiber 5 is connected with the detection signal input port of fiber distribution temperature measuring equipment 3.
The signal output port of the fiber distribution temperature measuring equipment 3 is connected with the detection signal input port of computer 4.
The fluid of oil gas water well of the present invention injects or the measurement method of output distribution flow are as follows: by optical fiber 5 and heating wires 6
Armouring is that composite cable 1 is vertically laid in pit shaft, and heating power supply 2 is powered heating wires 6, so that composite cable 1
Heating；
By the optical fiber in composite cable, the fiber optic Distributed Temperature of the touched fluid of composite cable 1 where measuring fluid；
Distributed fluid mass flow FiRelationship between (i-th section in fiber optic Distributed Temperature) and fiber optic Distributed Temperature is such as
Under:
Wherein IiTo pass through 1 i-th section of composite cable of electric current (electric currents of heating wires 6)；Ri is 1 i-th section of composite cable
Resistance (resistance of heating wires 6)；TiFor 1 i-th section of heating temperature of composite cable；TwFor 1 i-th section of heating of composite cable
Preceding temperature；A, B are empirical.
Above-mentioned calculating process can be completed by the computer 4.
The heating wires 6 are heated using full well section or the heating of part well section.
The full well section heating refers to: heating wires are a kind of conductor；Well section heating in part refers to: heating wires are two kinds
Conductor is spliced.
A kind of conductor refers to copper conductor or constantan conductor；Described two conductors refer to copper conductor and constantan conductor.
So-called full well section and point well section refer to the well of 1000 meters of depths, if heating wires are all a kind of conductors, for example copper is led
Body or constantan (also referred to as heater strip), then being the heating of 1000 meters of full well section while power is being supplied；If heating wires a part is
Copper conductor (900 meters of 1000 meters), a part are constantan conductor (in addition 100 meters), and when powering to conducting wire, usually constantan is led
Body fever, and copper conductor does not generate heat, while power is being supplied, infull well section heats the conducting wire or composite cable made in this way,
Part well section heating (only 100 meters are heating).
It can be measured for a certain section of flow in well using part well section heating method, without adding heating wires all
Heat, energy conservation, safety (being heated due to not having to full section, the high voltage that presses to heating wires is not necessarily to, so safer).
It is compound to be measured by the optical fiber in composite cable for fluid place using fiber distribution temperature measuring equipment 3 (DTS-8000)
The fiber optic Distributed Temperature of the touched fluid of optical cable 1.
It may also display fiber optic Distributed Temperature.
Fiber optic Distributed Temperature is shown on the computer 4, the fiber optic Distributed Temperature meter measured by fiber distribution temperature measuring equipment 3
Point counting cloth liquid mass flow.
The heating power for being supplied to certain section (such as i-th section in fiber optic Distributed Temperature) in composite cable 1 is equal to the section stream
The thermal energy that body heat convection carries away.That is:
Wherein IiTo pass through 1 i-th section of composite cable of electric current；RiFor 1 i-th section of resistance of composite cable；TiFor optical cable i-th
The heating temperature of section；TwFor the temperature before i-th section of optical cable of heating.H is the surface coefficient of heat conduction of composite cable 1；As is multiple
The surface area that 1 i-th section of light combination cable；Composite cable 1 be segmented i number it is related with the spatial resolution of fiber distribution temperature measuring equipment 3.
According to the empirical relation formula of BAKER, hAsIt can indicate are as follows:
Wherein FiPass through 1 i-th section of composite cable of mass flow for fluid；
It can be obtained by formula (1) and formula (2):
The method of determination of the A, B empirical are as follows: by the measurable injection or production for changing known resulting fluid
Outflow, due to heated current IiConstant and it is known that bringing-up section resistance RiIt is also known that by two kinds of different well head flow values, with
And under corresponding current stabilization state under conditions of fiber optic Distributed Temperature value, formula (3) is obtained about solution A, B empirical binary
Equation derives the A that distribution flow is calculated under the conditions of current hole condition, B empirical.
After the computer 4 is not powered in heating power supply 2, and fluid flows current stabilization in the wellbore, pass through fiber distribution
The measurement of temperature measuring equipment 3 obtains the districution temperature value T of composite cable 1w(w=1,2 ..., n), n is the total of fiber optic Distributed Temperature
Number of segment；
The computer 4 controls heating power supply 2 and carries out constant current I to the heating wires 6 in composite cable 1iPower supply, according to light
The 1 stranding parameter of spatial resolution and composite cable of fibre distribution temperature measuring equipment 3, RiIt is known；Wherein supply current IiSize
When with pit shaft maximum flow, can generate subject to the temperature change that fiber distribution temperature measuring equipment 3 can identify (such as maximum stream flow
When, temperature can heat up 5 DEG C)；After fiber optic Distributed Temperature thermal field is stablized, answered by the measurement of fiber distribution temperature measuring equipment 3
The districution temperature value T of light combination cablei(i=1,2 ..., n), n is total number of segment of fiber optic Distributed Temperature.
By calculation formula (3), successively calculates and be distributed the corresponding fluid mass stream of thermometric section in 1 bringing-up section of composite cable
Measure Fi(i=1,2 ..., n), n is total distribution flow number.
Injection or production profile on oil field refer to the absolute value of the top and bottom flow difference of the well difference payzone.
Knowing well head total flow FallUnder the premise of, and calculate payzone injection or production profile always flowed with well head
Measure FallWhen not being inconsistent, it is corrected by following formula；
Wherein PiFor the flow of the i-th output layer, FiIt is the i-th calculated flow of output layer, FjIt is that jth output layer calculates
Flow, m be payzone sum.
Judge that fluid is injection or output, is subject to fluid flow direction.
In order to which whether confirmatory measurement is accurate, by above mentioning or transferring composite cable 1, measurement is again to verify identical well depth stream
Whether body injection or output flow and the result for not proposing or transferring measurement above are consistent.
The present invention can measure the distribution flow of pit shaft measuring section in real time, while obtaining underground and respectively injecting or the note of output layer
Section is adopted, for instructing oil gas water well production to be of great significance.The calculating of fluid distrbution flow can be in known well head flow
On the basis of, by changing well head flow, empirical relevant to the well is obtained, self calibration is realized, so that measurement knot
Fruit is more in line with the traffic characteristic of real fluid.
The present invention is especially suitable for the specific heat capacities of measuring medium to adopt in the wellbore than more consistent oil gas water well, such as gas note
Well (such as natural gas, nitrogen, carbon dioxide, air etc.), the injection-production well etc. of water.
It is understood that being merely to illustrate the present invention above with respect to specific descriptions of the invention and being not limited to this
Technical solution described in inventive embodiments, those skilled in the art should understand that, still the present invention can be carried out
Modification or equivalent replacement, to reach identical technical effect；As long as meet use needs, all protection scope of the present invention it
It is interior.
Claims (10)
1. the fluid of oil gas water well injects or the measuring device of output distribution flow, including optical fiber (5) and heating wires (6),
It is characterized in that optical fiber (5) and heating wires (6) armouring is composite cable (1).
2. the measuring device of the fluid injection of oil gas water well or output distribution flow according to claim 1, it is characterised in that
The composite cable is stainless steel tube armouring composite cable.
3. the measuring device of the fluid injection of oil gas water well or output distribution flow according to claim 1, it is characterised in that
The optical fiber (5) is connected with the detection signal input port of fiber distribution temperature measuring equipment (3)；The fiber distribution temperature measuring equipment
(3) signal output port is connected with the detection signal input port of computer (4).
4. the fluid of oil gas water well injects or the measurement method of output distribution flow, it is characterised in that lead optical fiber (5) with heating
Line (6) armouring is that composite cable (1) is vertically laid in pit shaft, and heating power supply (2) is powered heating wires (6), makes
Obtain composite cable (1) heating；
By the optical fiber in composite cable, the fiber optic Distributed Temperature of composite cable (1) touched fluid where measuring fluid；
Distributed fluid mass flow FiRelationship between fiber optic Distributed Temperature is as follows:
Wherein IiTo pass through 1 i-th section of composite cable of electric current；RiFor 1 i-th section of resistance of composite cable；TiFor composite cable 1 i-th
The heating temperature of section；TwFor the temperature before 1 i-th section of composite cable of heating；A, B are empirical.
5. the measurement method of the fluid injection of oil gas water well or output distribution flow according to claim 4, it is characterised in that
The heating wires (6) are heated using full well section or the heating of part well section.
6. the measurement method of the fluid injection of oil gas water well or output distribution flow according to claim 5, it is characterised in that
The full well section heating refers to: heating wires are a kind of conductor；Well section heating in part refers to: heating wires are two kinds of conductor splicings
It forms.
7. the measurement method of the fluid injection of oil gas water well or output distribution flow according to claim 4, it is characterised in that
Using fiber distribution temperature measuring equipment (3), pass through composite cable (1) touched fluid where the optical fiber measurement fluid in composite cable
Fiber optic Distributed Temperature；Fiber optic Distributed Temperature is shown on computer (4), the optical fiber measured by fiber distribution temperature measuring equipment (3)
Districution temperature calculates Distributed fluid mass flow.
8. the measurement method of the fluid injection of oil gas water well or output distribution flow according to claim 4, it is characterised in that
The method of determination of the A, B empirical are as follows: by changing measurable injection or the output flow of known resulting fluid, by
In heated current IiConstant and it is known that bringing-up section resistance RiIt is also known that passing through two kinds of different well head flow values and corresponding
Current stabilization state under under conditions of fiber optic Distributed Temperature value, obtain formula and derived about A, B empirical equation with two unknowns is solved
The A of distribution flow, B empirical are calculated under the conditions of current hole condition.
9. the measurement method of the fluid injection of oil gas water well or output distribution flow according to claim 4, it is characterised in that
After computer (4) is not powered in heating power supply (2), and fluid flows current stabilization in the wellbore, pass through fiber distribution temperature measuring equipment
(3) measurement obtains the districution temperature value T of composite cable (1)w(w=1,2 ..., n), n is the block of fiber optic Distributed Temperature
Number；
Computer (4) controls heating power supply (2) and carries out constant current I to the heating wires (6) in composite cable 1iPower supply, according to optical fiber
It is distributed the spatial resolution and composite cable (1) stranding parameter of temperature measuring equipment (3), RiIt is known；Wherein supply current IiIt is big
When the small maximum flow with pit shaft, can generate subject to the temperature change that fiber distribution temperature measuring equipment (3) can identify (such as it is maximum
When flow, temperature can heat up 5 DEG C or more)；After fiber optic Distributed Temperature thermal field is stablized, pass through fiber distribution temperature measuring equipment (3)
Measurement obtains the districution temperature value T of composite cablei(i=1,2 ..., n), n is total number of segment of fiber optic Distributed Temperature.
By calculation formula (3), successively calculates and be distributed the corresponding liquid mass flow F of thermometric section in 1 bringing-up section of composite cablei
(i=1,2 ..., n), n is total distribution flow number.
10. the measurement method of the fluid injection of oil gas water well or output distribution flow according to claim 4, it is characterised in that
Knowing well head total flow FallUnder the premise of, and injection or production profile and the well head total flow F of the payzone calculatedallIt is not inconsistent
When, it is corrected by following formula；
Wherein PiFor the flow of the i-th output layer, FiIt is the i-th calculated flow of output layer, FjIt is the calculated stream of jth output layer
Amount, m are payzone sums.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201910433003.7A CN110185434B (en) | 2019-05-23 | 2019-05-23 | Measuring device and method for fluid injection or production distribution flow of oil-gas-water well |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201910433003.7A CN110185434B (en) | 2019-05-23 | 2019-05-23 | Measuring device and method for fluid injection or production distribution flow of oil-gas-water well |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN110185434A true CN110185434A (en) | 2019-08-30 |
| CN110185434B CN110185434B (en) | 2023-03-17 |
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ID=67717521
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| CN201910433003.7A Active CN110185434B (en) | 2019-05-23 | 2019-05-23 | Measuring device and method for fluid injection or production distribution flow of oil-gas-water well |
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Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN113530524A (en) * | 2021-07-12 | 2021-10-22 | 中国石油大学(华东) | Shaft flow monitoring system and flow and water content interpretation method |
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| CN113530524B (en) * | 2021-07-12 | 2023-05-26 | 中国石油大学(华东) | Shaft flow monitoring system and flow and water content interpretation method |
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