CN107387039A - Utilize the method for the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot - Google Patents
Utilize the method for the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot Download PDFInfo
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- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 title claims abstract description 149
- 229910002092 carbon dioxide Inorganic materials 0.000 title claims abstract description 82
- 239000001569 carbon dioxide Substances 0.000 title claims abstract description 80
- 238000000034 method Methods 0.000 title claims abstract description 52
- 238000009530 blood pressure measurement Methods 0.000 title claims abstract description 23
- 238000002347 injection Methods 0.000 claims abstract description 167
- 239000007924 injection Substances 0.000 claims abstract description 167
- 238000004519 manufacturing process Methods 0.000 claims abstract description 58
- 238000005259 measurement Methods 0.000 claims abstract description 16
- 239000010779 crude oil Substances 0.000 claims description 28
- 238000012360 testing method Methods 0.000 claims description 28
- 230000001052 transient effect Effects 0.000 claims description 26
- 230000008569 process Effects 0.000 claims description 21
- 230000008859 change Effects 0.000 claims description 16
- 230000035699 permeability Effects 0.000 claims description 14
- 238000002474 experimental method Methods 0.000 claims description 12
- 238000004364 calculation method Methods 0.000 claims description 7
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims description 5
- ONIBWKKTOPOVIA-UHFFFAOYSA-N Proline Chemical compound OC(=O)C1CCCN1 ONIBWKKTOPOVIA-UHFFFAOYSA-N 0.000 claims description 5
- 230000015572 biosynthetic process Effects 0.000 claims description 5
- 229910052799 carbon Inorganic materials 0.000 claims description 5
- 239000012530 fluid Substances 0.000 claims description 5
- 239000003129 oil well Substances 0.000 claims description 5
- GWEVSGVZZGPLCZ-UHFFFAOYSA-N Titan oxide Chemical compound O=[Ti]=O GWEVSGVZZGPLCZ-UHFFFAOYSA-N 0.000 claims description 4
- 238000007796 conventional method Methods 0.000 claims description 3
- 239000004408 titanium dioxide Substances 0.000 claims description 2
- 238000011161 development Methods 0.000 abstract description 6
- 238000005516 engineering process Methods 0.000 description 7
- 239000003921 oil Substances 0.000 description 7
- 238000004088 simulation Methods 0.000 description 7
- 238000010586 diagram Methods 0.000 description 6
- 241000790917 Dioxys <bee> Species 0.000 description 3
- 230000005465 channeling Effects 0.000 description 3
- 238000006073 displacement reaction Methods 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- 239000000700 radioactive tracer Substances 0.000 description 3
- 238000010998 test method Methods 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 238000009826 distribution Methods 0.000 description 2
- 238000005065 mining Methods 0.000 description 2
- 241000184339 Nemophila maculata Species 0.000 description 1
- GCNLQHANGFOQKY-UHFFFAOYSA-N [C+4].[O-2].[O-2].[Ti+4] Chemical compound [C+4].[O-2].[O-2].[Ti+4] GCNLQHANGFOQKY-UHFFFAOYSA-N 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 239000004744 fabric Substances 0.000 description 1
- 238000011002 quantification Methods 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000001603 reducing effect Effects 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 239000009671 shengli Substances 0.000 description 1
- 238000004513 sizing Methods 0.000 description 1
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- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/164—Injecting CO2 or carbonated water
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- 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
- E21B47/06—Measuring temperature or pressure
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- G—PHYSICS
- G16—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR SPECIFIC APPLICATION FIELDS
- G16Z—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR SPECIFIC APPLICATION FIELDS, NOT OTHERWISE PROVIDED FOR
- G16Z99/00—Subject matter not provided for in other main groups of this subclass
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Abstract
The present invention provides a kind of method using the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot, and this is included using the method for the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot：Step 1, determine that gas injection well, producing well survey continuous flowing bottomhole pressure (FBHP), surveying continuous flowing bottomhole pressure (FBHP) according to gas injection well, producing well calculates the continuous injection production pressure difference of actual measurement；Step 2, the theoretical continuous flowing bottomhole pressure (FBHP) of gas injection well, producing well is calculated, and according to gas injection well, the continuous injection production pressure difference of the theoretical continuous flowing bottomhole pressure (FBHP) computational theory of producing well；Step 3, carbon dioxide additional pressure drop is calculated according to actual measurement and theoretical continuous injection production pressure difference, inverting carbon dioxide is equivalent to involve radius.This using the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot methods and resultses it is accurate, be easily achieved, to improving carbon dioxide flooding development effectiveness, realize that carbon dioxide flooding oil reservoir scientific management is significant.
Description
Technical field
The present invention relates to carbon dioxide flooding leading edge in oil-gas field development to evaluate field, especially relates to one kind and utilizes multiple spot
The method of continuous pressure measurement data inversion carbon dioxide flooding leading edge.
Background technology
Carbon dioxide flooding shows the advantage of uniqueness in terms of solving development of low-permeability oil reservoir.During field test, instead
Mirroring carbon dioxide flooding has stronger has channeling feature, and difference on effect of taping the latent power is very big, and is difficult to merely from carbon dioxide output
Angular quantification recognizes.Therefore, it is necessary to from the angle of field measured data, point of accurate description subterranean carbon dioxide displacing front
Cloth.Currently used method includes microseism method and inter-well tracer test method of testing between numerical simulation technology, well.But numerical simulation
Technology is high to data demand, simulation cycle length；Microseism method and inter-well tracer test method of testing cost are higher between well, it is difficult to describe
The change of has channeling early stage carbon dioxide leading edge, and the consecutive variations situation of carbon dioxide displacement leading edge can not be obtained.
Due to the consecutive variations of carbon dioxide displacement leading edge can not be described accurately, in time, low-permeability oil deposit titanium dioxide at present
Carbon drives that exploitation has that has channeling is serious, development effectiveness is poor and working system adjusts shortage foundation in time, and development management hysteresis is asked
Topic.For this we have invented a kind of new method using the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot, it is utilized
The continuous flowing bottomhole pressure (FBHP) data that scene most easily obtains, realize the equivalent quick and continuous inverting for involving radius of carbon dioxide flooding.
The content of the invention
It is an object of the invention to provide a kind of new method using the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot,
Based on the continuous flowing bottomhole pressure (FBHP) data that mining site most easily obtains, realize that carbon dioxide is equivalent and involve the quick of radius and continuous anti-
Drill.
The purpose of the present invention can be achieved by the following technical measures：Utilize the continuous pressure measurement data inversion carbon dioxide of multiple spot
The method for driving leading edge, this is included using the method for the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot：Step 1, it is determined that note
Gas well, producing well survey continuous flowing bottomhole pressure (FBHP), survey the continuous continuous note of flowing bottomhole pressure (FBHP) calculating actual measurement according to gas injection well, producing well and adopt
Pressure difference；Step 2, the theoretical continuous flowing bottomhole pressure (FBHP) of gas injection well, producing well is calculated, and according to gas injection well, the theoretical continuous shaft bottom of producing well
Manoscope calculates theoretical continuous injection production pressure difference；Step 3, carbon dioxide additonal pressure is calculated according to actual measurement and theoretical continuous injection production pressure difference
Drop, inverting carbon dioxide is equivalent to involve radius.
The purpose of the present invention can be also achieved by the following technical measures：
In step 1, continuous injection production pressure difference Δ p is surveyedh(t) refer to gas injection well and survey continuous flowing bottomhole pressure (FBHP) pinj-h(t) with adopting
Oil well surveys continuous flowing bottomhole pressure (FBHP) ppro-h(t) difference, definition are：
Δph(t)=pinj-h(t)-ppro-h(t) formula (1)
In formula, t --- the testing time, s.
The gas injection well surveys continuous flowing bottomhole pressure (FBHP) pinj-h(t) actual continuous flowing bottomhole pressure (FBHP) in gas injection well injection process is referred to,
It can directly be measured by the lower pressure gauge to shaft bottom, can also be rolled over according to a conventional method according to well head to any depth pressure data in shaft bottom
Obtain；
The producing well surveys continuous flowing bottomhole pressure (FBHP) ppro-h(t) actual continuous shaft bottom during Production Wells or closing well is referred to
Stream pressure, it can directly be measured by the lower pressure gauge to shaft bottom, also can be according to well head to any depth pressure data in shaft bottom routinely
Method converts to obtain.
In step 1, the continuous flowing bottomhole pressure (FBHP) refers to the flowing bottomhole pressure (FBHP) under same time interval, and time interval is according to gas injection
Well, producing well flowing bottomhole pressure (FBHP) data distribution determine；
In step 2, the theoretical continuous injection production pressure difference Δ ps(t) the theoretical continuous flowing bottomhole pressure (FBHP) p of gas injection well is referred toinj-s(t)
With the theoretical continuous flowing bottomhole pressure (FBHP) p of producing wellpro-s(t) difference, definition are：
Δps(t)=pinj-s(t)-ppro-s(t) formula (2)
In formula, t --- the testing time, s.
The theoretical continuous flowing bottomhole pressure (FBHP) p of the gas injection wellinj-s(t) the continuous flowing bottomhole pressure (FBHP) p of gas injection well is referred toinj(rw, t) and with recovering the oil
Well pressure change, elta p caused by the injection wellpro(L, t) sum, is shown below：
pinj-s(t)=pinj(rw,t)+Δppro(L, t) formula (3)
In formula, rw--- wellbore radius, cm；
L --- injector producer distance, cm.
The theoretical continuous flowing bottomhole pressure (FBHP) p of the producing wellpro-s(t) the continuous flowing bottomhole pressure (FBHP) p of producing well is referred topro(rw, t) and gas injection
Well pressure change, elta p caused by the producing wellinj(L, t) sum, is shown below：
ppro-s(t)=ppro(rw,t)+Δpinj(L, t) formula (6)
In formula, rw--- wellbore radius, cm；
L --- injector producer distance, cm.
In step 2, the continuous flowing bottomhole pressure (FBHP) p of gas injection wellinj(rw, t) it is calculated by transient seepage flow formula：
In formula, μoil--- underground crude oil viscosity, mPa.s, measured by crude oil PVT experiments；
qgas--- underground gas injection speed, cm3/ s, obtained according to gas injection well dynamic data；
kinj--- the nearly well permeability of gas injection well, μm2, explain to obtain according to the gas injection well single-well transient testing of routine；
hinj--- gas injection well well point effective thickness, cm, obtained according to well log interpretation achievement；
ηi nj--- gas injection well piezometric conductivity,
φinj--- gas injection well well point porosity, f, obtained according to well log interpretation achievement；
ct--- system compressibility, atm‐1；
T --- testing time, s；
λ --- free-boundary problem, atm/cm；
pi--- original formation pressure, atm.
For Production Wells process, producing well pressure change, elta p caused by the injection wellpro(L, t) is oozed by unstable
Stream formula is calculated：
In formula, μoil--- underground crude oil viscosity, mPa.s, measured by crude oil PVT experiments；
qoil--- underground fluid production rate, cm3/ s, obtained according to producing well dynamic data；
kpro--- the nearly well permeability of producing well, μm2, explain to obtain according to producing well single-well transient testing；
hpro--- producing well well point effective thickness, cm, obtained according to well log interpretation achievement；
ηpro--- producing well piezometric conductivity,
φpro--- producing well well point porosity, f, obtained according to well log interpretation achievement；
L --- injector producer distance, cm.
For producing well closing well process, Δ ppro(L, t) is tried to achieve by formula (5) and normal pressures principle of stacking.
In step 2, for Production Wells process, the continuous flowing bottomhole pressure (FBHP) p of producing wellpro(rw, t) and by transient seepage flow
Formula is calculated：
In formula, μoil--- underground crude oil viscosity, mPa.s, measured by crude oil PVT experiments；
qoil--- underground fluid production rate, cm3/ s, obtained according to producing well dynamic data；
kpro--- the nearly well permeability of producing well, μm2, explain to obtain according to producing well single-well transient testing；
hpro--- producing well well point effective thickness, cm, obtained according to well log interpretation achievement；
ηpro--- producing well piezometric conductivity,
φpro--- producing well well point porosity, f, obtained according to well log interpretation achievement；
ct--- system compressibility, atm‐1；
T --- testing time, s；
λ --- free-boundary problem, atm/cm；
pi--- original formation pressure, atm.
For producing well closing well process, ppro(rw, t) tried to achieve by formula (7) and normal pressures principle of stacking；
Gas injection well pressure change, elta p caused by the producing wellinj(L, t) is calculated by transient seepage flow formula：
In formula, μoil--- underground crude oil viscosity, mPa.s, measured by crude oil PVT experiments；
qgas--- underground gas injection speed, cm3/ s, obtained according to gas injection well dynamic data；
kinj--- the nearly well permeability of gas injection well, μm2, explain to obtain according to the gas injection well single-well transient testing of routine；
hinj--- gas injection well well point effective thickness, cm, obtained according to well log interpretation achievement；
ηi nj--- gas injection well piezometric conductivity,
φinj--- gas injection well well point porosity, f, obtained according to well log interpretation achievement；
ct--- system compressibility, atm‐1；
T --- testing time, s；
L --- injector producer distance, cm.
In step 3, when calculating carbon dioxide additional pressure drop, dioxy is calculated according to actual measurement and theoretical continuous injection production pressure difference
Change carbon additional pressure drop, specific formula for calculation is：
In formula,--- carbon dioxide additional pressure drop, atm；
Δps(t) --- theoretical continuous injection production pressure difference, atm；
Δph(t) --- survey continuous injection production pressure difference, atm.
Calculate CO2It is equivalent involve radius specific formula for calculation be：
In formula：D --- gas injection speed splits a point coefficient, and a line producing well number determines according to corresponding to gas injection well；
R (t) --- carbon dioxide is equivalent to involve radius, cm；
kinj--- the nearly well permeability of gas injection well, μm2, explain to obtain according to the gas injection well single-well transient testing of routine；
hinj--- gas injection well well point effective thickness, cm, obtained according to well log interpretation achievement；
μoil--- underground crude oil viscosity, mPa.s, measured by crude oil PVT experiments；
qgas--- underground gas injection speed, cm3/ s, obtained according to gas injection well dynamic data；
rw--- wellbore radius, cm；
--- carbon dioxide involve in the range of crude oil fifty-fifty descend viscosity, mPa.s, tried to achieve according to following formula：
In formula：——CO2Underground viscosity, mPa.s；
A --- viscosity mean coefficient.
The method using the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot in the present invention, due to carbon dioxide wave
And the viscosity reduction effect in scope so that continuous injection production pressure difference is surveyed between well and is less than theoretical continuous injection production pressure difference, so, use titanium dioxide
Carbon additional pressure drop describes the viscosity reducing effect that carbon dioxide involves scope, the flowing bottomhole pressure (FBHP) data most easily obtained in practice from mining site
Start with, involve radius with carbon dioxide additional pressure drop inverting carbon dioxide is equivalent：Continuous well is surveyed according to gas injection well, producing well
Underflow pressure, which calculates, surveys continuous injection production pressure difference；According to gas injection well, the theoretical continuous flowing bottomhole pressure (FBHP) computational theory of producing well, continuously note is adopted
Pressure difference；Carbon dioxide additional pressure drop is calculated, inverting carbon dioxide is equivalent to involve radius.This method cost is cheap, based on continuous
Pressure measurement data carry out carbon dioxide flooding leading edge fast inversion, to improving carbon dioxide flooding development effectiveness, realize oil reservoir scientific management
It is significant.
Brief description of the drawings
Fig. 1 is a specific implementation of the method using the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot of the present invention
The flow chart of example；
Fig. 2 is gas injection well P0 in embodiment two, producing well P1, P2 survey flowing bottomhole pressure (FBHP) schematic diagram；
Fig. 3 is the continuous injection production pressure difference schematic diagram of actual measurement of gas injection well P0 and producing well P1, P2 in embodiment two；
Fig. 4 is gas injection well P0, producing well P1, P2 theory flowing bottomhole pressure (FBHP) schematic diagram in embodiment two；
Fig. 5 is the continuous injection production pressure difference schematic diagram of theory of gas injection well P0 and producing well P1, P2 in embodiment two；
Fig. 6, which is that producing well P1 well carbon dioxide is equivalent in embodiment two, involves radius comparison diagram；
Fig. 7, which is that producing well P2 well carbon dioxide is equivalent in embodiment two, involves radius comparison diagram.
Embodiment
For enable the present invention above and other objects, features and advantages become apparent, it is cited below particularly go out preferable implementation
Example, and coordinate shown in accompanying drawing, it is described in detail below.
Embodiment one：
As shown in figure 1, Fig. 1 is the method using the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot of the present invention
Flow chart.
In step 100, calculate and survey continuous injection production pressure difference, specific steps include determining that gas injection well surveys continuous flowing bottomhole pressure (FBHP)
Step 110, determine that producing well surveys continuous flowing bottomhole pressure (FBHP) step 120 and calculates the continuous injection production pressure difference step 130 of actual measurement.
The continuous injection production pressure difference Δ p of actual measurementh(t) refer to gas injection well and survey continuous flowing bottomhole pressure (FBHP) pinj-h(t) it is real with producing well
Survey continuous flowing bottomhole pressure (FBHP) ppro-h(t) difference, definition are：
Δph(t)=pinj-h(t)-ppro-h(t) formula (1)
In formula, t --- the testing time, s.
The gas injection well surveys continuous flowing bottomhole pressure (FBHP) pinj-h(t) actual continuous flowing bottomhole pressure (FBHP) in gas injection well injection process is referred to,
It can directly be measured by the lower pressure gauge to shaft bottom, can also be rolled over according to a conventional method according to well head to any depth pressure data in shaft bottom
Obtain.
The producing well surveys continuous flowing bottomhole pressure (FBHP) ppro-h(t) actual continuous shaft bottom during Production Wells or closing well is referred to
Stream pressure, it can directly be measured by the lower pressure gauge to shaft bottom, also can be according to well head to any depth pressure data in shaft bottom routinely
Method converts to obtain.
The producing well refers to a line producing well of above-mentioned gas injection well.
The continuous flowing bottomhole pressure (FBHP) refers to the flowing bottomhole pressure (FBHP) under same time interval, and time interval can be according to gas injection well, oil recovery
Well flowing bottomhole pressure (FBHP) data distribution determines, is recommended as 1 day.
The determination gas injection well is surveyed continuous flowing bottomhole pressure (FBHP) step 110 and referred to according to the lower pressure gauge to shaft bottom or well head to well
Any depth pressure data in bottom determine actual continuous flowing bottomhole pressure (FBHP) p in gas injection well injection processinj-h(t) process.
The determination producing well is surveyed continuous flowing bottomhole pressure (FBHP) step 120 and referred to according to the lower pressure gauge to shaft bottom or well head to well
Any depth pressure data in bottom determine actual continuous flowing bottomhole pressure (FBHP) p during Production Wells or closing wellpro-h(t) process.
The continuous injection production pressure difference step 130 of actual measurement that calculates refers to the mistake for being calculated according to formula (1) and surveying continuous injection production pressure difference
Journey.
In step 200, the continuous injection production pressure difference of computational theory, specific steps include calculating the theoretical continuous flowing bottomhole pressure (FBHP) of gas injection well
Step 210, calculate the theoretical continuous flowing bottomhole pressure (FBHP) step 220 of producing well and the continuous injection production pressure difference step 230 of computational theory.
The theoretical continuous injection production pressure difference Δ ps(t) the theoretical continuous flowing bottomhole pressure (FBHP) p of gas injection well is referred toinj-s(t) managed with producing well
By continuous flowing bottomhole pressure (FBHP) ppro-s(t) difference, definition are：
Δps(t)=pinj-s(t)-ppro-s(t) formula (2)
The theoretical continuous flowing bottomhole pressure (FBHP) p of the gas injection wellinj-s(t) the continuous flowing bottomhole pressure (FBHP) p of gas injection well is referred toinj(rw, t) and with recovering the oil
Well pressure change, elta p caused by the injection wellpro(L, t) sum, as shown in formula (3).
pinj-s(t)=pinj(rw,t)+Δppro(L, t) formula (3)
In formula, rw--- wellbore radius, cm.
Specifically, the continuous flowing bottomhole pressure (FBHP) p of gas injection wellinj(rw, t) it is calculated by transient seepage flow formula (4).
In formula, μoil--- underground crude oil viscosity, mPa.s, measured by crude oil PVT experiments；
qgas--- underground gas injection speed, cm3/ s, obtained according to gas injection well dynamic data；
kinj--- the nearly well permeability of gas injection well, μm2, explain to obtain according to the gas injection well single-well transient testing of routine；
hinj--- gas injection well well point effective thickness, cm, obtained according to well log interpretation achievement；
ηinj--- gas injection well piezometric conductivity,
φinj--- gas injection well well point porosity, f, obtained according to well log interpretation achievement；
ct--- system compressibility, atm‐1；
T --- testing time, s；
λ --- free-boundary problem, atm/cm；
pi--- original formation pressure, atm.
Specifically, for Production Wells process, producing well pressure change, elta p caused by the injection wellpro(L, t) by
Transient seepage flow formula (5) is calculated.
In formula, μoIl --- underground crude oil viscosity, mPa.s, measured by crude oil PVT experiments；
qoil--- underground fluid production rate, cm3/ s, obtained according to producing well dynamic data；
kpro--- the nearly well permeability of producing well, μm2, explain to obtain according to producing well single-well transient testing；
hpro--- producing well well point effective thickness, cm, obtained according to well log interpretation achievement；
ηpro--- producing well piezometric conductivity,
φpro--- producing well well point porosity, f, obtained according to well log interpretation achievement；
L --- injector producer distance, cm.
For producing well closing well process, Δ ppro(L, t) is tried to achieve by formula (5) and normal pressures principle of stacking, no longer superfluous
State.
The theoretical continuous flowing bottomhole pressure (FBHP) p of the producing wellpro-s(t) the continuous flowing bottomhole pressure (FBHP) p of producing well is referred topro(rw, t) and gas injection
Well pressure change, elta p caused by the producing wellinj(L, t) sum, as shown in formula (6).
ppro-s(t)=ppro(rw,t)+Δpinj(L, t) formula (6)
Specifically, for Production Wells process, the continuous flowing bottomhole pressure (FBHP) p of producing wellpro(rw, t) and by transient seepage flow formula
(7) it is calculated.
For producing well closing well process, ppro(rw, t) tried to achieve by formula (7) and normal pressures principle of stacking, repeat no more.
Specifically, gas injection well pressure change, elta p caused by the producing wellinj(L, t) is counted by transient seepage flow formula (8)
Obtain.
The theoretical continuous flowing bottomhole pressure (FBHP) step 210 of calculating gas injection well refers to be calculated according to transient seepage flow formula (3)
Gas injection well injection process in theoretical continuous flowing bottomhole pressure (FBHP) process.
The theoretical continuous flowing bottomhole pressure (FBHP) step 220 of calculating producing well refers to folds according to transient seepage flow formula (6) and pressure
Add the process of theoretical continuous flowing bottomhole pressure (FBHP) during the gas injection well injection or closing well that principle is calculated.
The continuous injection production pressure difference step 230 of computational theory refers to the mistake according to the continuous injection production pressure difference of formula (2) computational theory
Journey.
In step 300, determine that carbon dioxide is equivalent and involve radius, specifically include meter carbon dioxide additional pressure drop step
310th, calculate that carbon dioxide is equivalent involves radius step 320.
The calculating carbon dioxide additional pressure drop step 310 refers to calculates dioxy according to actual measurement and theoretical continuous injection production pressure difference
Change the process of carbon additional pressure drop, specific formula for calculation is：
In formula,--- carbon dioxide additional pressure drop, atm.
The equivalent radius step 320 that involves of the calculating carbon dioxide involves half for determining that continuous carbon dioxide is equivalent
Footpath, specific formula for calculation are：
In formula：D --- gas injection speed splits a point coefficient, and a line producing well number determines according to corresponding to gas injection well；
R (t) --- carbon dioxide is equivalent to involve radius, cm；
--- carbon dioxide involve in the range of crude oil fifty-fifty descend viscosity, m Pa.s, tried to achieve according to formula (11)：
In formula：--- carbon dioxide underground viscosity, m Pa.s；
A --- viscosity mean coefficient, oil from Shengli oil field property is recommended to take 2.5.
Embodiment two：The equivalent radius calculation result that involves of carbon dioxide contrasts with numerical simulation technology
Utilize pressure difference transient well test method validity between component theoretical model checking injection-production well.Design component theory mould
Type, geological model plane sizes are 999m × 999m, 111 × 111 × 3=36963 of gridding dimension, sizing grid 9m × 9m ×
5m.Encrypt the grid in nearly well 180m × 180m regions, refined net 123 × 123 × 3=45387 of dimension, refined net size
3m×3m×1m.Model is five-spot pattern, producing well P1, P3, fluid-channeling channel, permeability between P2, P4 well and gas injection well P0 be present
Respectively 25,100 × 10‐3μm2。
Continuous injection production pressure difference is surveyed 1. calculating
Gas injection well P0 and producing well P1, P2 the actual measurement flowing bottomhole pressure (FBHP) (table 1, Fig. 2) obtained using numerical simulation, calculates actual measurement
Continuous injection production pressure difference (table 1, Fig. 3).
The gas injection well P0 of table 1, producing well P1, P2 actual measurement flowing bottomhole pressure (FBHP) and the continuous injection production pressure difference of actual measurement
2. the continuous injection production pressure difference of computational theory
Gas injection well P0 and the nearly well permeability of producing well P1, P2 are all 5 × 10‐3μm2, it is calculated using formula (2)~(8)
Theoretical continuous flowing bottomhole pressure (FBHP) and theoretical continuous injection production pressure difference (table 2, Fig. 4, Fig. 5).
The gas injection well P0 of table 2, producing well P1, P2 theory flowing bottomhole pressure (FBHP) and theoretical continuous injection production pressure difference
2. calculating, carbon dioxide is equivalent to involve radius
The difference of theoretical continuous injection production pressure difference and actual continuous injection production pressure difference is exactly carbon dioxide additional pressure drop(table
3), P1 wells, the equivalent radius that involves of carbon dioxide corresponding to P2 wells be as shown in table 3, Fig. 6, Fig. 7, and parameter used is as follows during calculating
It is listed：
Totally 4 mouthfuls of producing wells, so gas injection speed splits point coefficient as 0.25；Underground crude oil viscosity 2.8mPa.s, underground dioxy
Change carbon viscosity 0.04mPa.s；Wellbore radius 0.1m, injector producer distance 450m；Gas injection well, producing well well point effective thickness 30m.
The carbon dioxide additional pressure drop of table 3
" carbon dioxide etc. that " carbon dioxide involves leading edge " and the conservation of matter obtained with numerical simulation technology is calculated
Effect involves leading edge " contrast, the equivalent reasonability for involving radius of carbon dioxide that new technology obtains on the one hand is demonstrated, on the other hand
It specify that the unavailability of conservation of matter method in the presence of anisotropism.
The method using the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot in the present invention, using gas injection well, is adopted
The continuous pressure measurement data of oil well realize the equivalent fast inversion for involving radius of carbon dioxide, compensate for existing numerical simulation skill
Microseism method and inter-well tracer test technology realize carbon dioxide drive it is determined that the defects of carbon dioxide flooding leading edge between art, well
Continuous tracking of the gas displacement front using day as chronomere is hidden, is advantageously used for the timely adjustment of working system in reservoir management.
Claims (6)
1. utilize the method for the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot, it is characterised in that this is continuous using multiple spot
The method of pressure measurement data inversion carbon dioxide flooding leading edge includes：
Step 1, determine that gas injection well, producing well survey continuous flowing bottomhole pressure (FBHP), continuous flowing bottomhole pressure (FBHP) is surveyed according to gas injection well, producing well
Calculate and survey continuous injection production pressure difference；
Step 2, the theoretical continuous flowing bottomhole pressure (FBHP) of gas injection well, producing well is calculated, and according to gas injection well, the theoretical continuous shaft bottom stream of producing well
Press the continuous injection production pressure difference of computational theory；
Step 3, carbon dioxide additional pressure drop, the equivalent ripple of inverting carbon dioxide are calculated according to actual measurement and theoretical continuous injection production pressure difference
And radius.
2. the method according to claim 1 using the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot, its feature
It is, in step 1, surveys continuous injection production pressure difference Δ ph(t) refer to gas injection well and survey continuous flowing bottomhole pressure (FBHP) pinj-hAnd producing well (t)
Survey continuous flowing bottomhole pressure (FBHP) ppro-h(t) difference, definition are：
Δph(t)=pinj-h(t)-ppro-h(t) formula (1)
In formula, t --- the testing time, s.
The gas injection well surveys continuous flowing bottomhole pressure (FBHP) pinj-h(t) actual continuous flowing bottomhole pressure (FBHP) in gas injection well injection process is referred to, it can
Directly measured by the lower pressure gauge to shaft bottom, can also be converted according to a conventional method according to well head to any depth pressure data in shaft bottom
Arrive；
The producing well surveys continuous flowing bottomhole pressure (FBHP) ppro-h(t) actual continuous shaft bottom is flowed during referring to Production Wells or closing well
Pressure, it can directly be measured by the lower pressure gauge to shaft bottom, also can be routinely square according to well head to any depth pressure data in shaft bottom
Method converts to obtain.
3. the method according to claim 1 using the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot, its feature
It is, in step 2, the theoretical continuous injection production pressure difference Δ ps(t) the theoretical continuous flowing bottomhole pressure (FBHP) p of gas injection well is referred toinj-s(t) with adopting
The theoretical continuous flowing bottomhole pressure (FBHP) p of oil wellpro-s(t) difference, definition are：
Δps(t)=pinj-s(t)-ppro-s(t) formula (2)
In formula, t --- the testing time, s.
The theoretical continuous flowing bottomhole pressure (FBHP) p of the gas injection wellinj-s(t) the continuous flowing bottomhole pressure (FBHP) p of gas injection well is referred toinj(rw, t) exist with producing well
Pressure change, elta p caused by injection wellpro(L, t) sum, is shown below：
pinj-s(t)=pinj(rw,t)+Δppro(L, t) formula (3)
In formula, rw--- wellbore radius, cm；
L --- injector producer distance, cm.
The theoretical continuous flowing bottomhole pressure (FBHP) p of the producing wellpro-s(t) the continuous flowing bottomhole pressure (FBHP) p of producing well is referred topro(rw, t) exist with gas injection well
Pressure change, elta p caused by producing wellinj(L, t) sum, is shown below：
ppro-s(t)=ppro(rw,t)+Δpinj(L, t) formula (6)
In formula, rw--- wellbore radius, cm；
L --- injector producer distance, cm.
4. the method according to claim 3 using the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot, its feature
It is, in step 2, the continuous flowing bottomhole pressure (FBHP) p of gas injection wellinj(rw, t) it is calculated by transient seepage flow formula：
In formula, μoil--- underground crude oil viscosity, mPa.s, measured by crude oil PVT experiments；
qgas--- underground gas injection speed, cm3/ s, obtained according to gas injection well dynamic data；
kinj--- the nearly well permeability of gas injection well, μm2, explain to obtain according to the gas injection well single-well transient testing of routine；
hinj--- gas injection well well point effective thickness, cm, obtained according to well log interpretation achievement；
ηinj--- gas injection well piezometric conductivity,
φinj--- gas injection well well point porosity, f, obtained according to well log interpretation achievement；
ct--- system compressibility, atm‐1；
T --- testing time, s；
λ --- free-boundary problem, atm/cm；
pi--- original formation pressure, atm.
For Production Wells process, producing well pressure change, elta p caused by the injection wellpro(L, t) is public by transient seepage flow
Formula is calculated：
In formula, μoil--- underground crude oil viscosity, mPa.s, measured by crude oil PVT experiments；
qoil--- underground fluid production rate, cm3/ s, obtained according to producing well dynamic data；
kpro--- the nearly well permeability of producing well, μm2, explain to obtain according to producing well single-well transient testing；
hpro--- producing well well point effective thickness, cm, obtained according to well log interpretation achievement；
ηpro--- producing well piezometric conductivity,
φpro--- producing well well point porosity, f, obtained according to well log interpretation achievement；
L --- injector producer distance, cm.
For producing well closing well process, Δ ppro(L, t) is tried to achieve by formula (5) and normal pressures principle of stacking.
5. the method according to claim 3 using the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot, its feature
It is, in step 2, for Production Wells process, the continuous flowing bottomhole pressure (FBHP) p of producing wellpro(rw, t) and by transient seepage flow formula
It is calculated：
In formula, μoil--- underground crude oil viscosity, mPa.s, measured by crude oil PVT experiments；
qoil--- underground fluid production rate, cm3/ s, obtained according to producing well dynamic data；
kpro--- the nearly well permeability of producing well, μm2, explain to obtain according to producing well single-well transient testing；
hpro--- producing well well point effective thickness, cm, obtained according to well log interpretation achievement；
ηpro--- producing well piezometric conductivity,
φpro--- producing well well point porosity, f, obtained according to well log interpretation achievement；
ct--- system compressibility, atm‐1；
T --- testing time, s；
λ --- free-boundary problem, atm/cm；
pi--- original formation pressure, atm.
For producing well closing well process, ppro(rw, t) tried to achieve by formula (7) and normal pressures principle of stacking；
Gas injection well pressure change, elta p caused by the producing wellinj(L, t) is calculated by transient seepage flow formula：
In formula, μoil--- underground crude oil viscosity, mPa.s, measured by crude oil PVT experiments；
qgas--- underground gas injection speed, cm3/ s, obtained according to gas injection well dynamic data；
kinj--- the nearly well permeability of gas injection well, μm2, explain to obtain according to the gas injection well single-well transient testing of routine；
hinj--- gas injection well well point effective thickness, cm, obtained according to well log interpretation achievement；
ηinj--- gas injection well piezometric conductivity,
φinj--- gas injection well well point porosity, f, obtained according to well log interpretation achievement；
T --- testing time, s；
L --- injector producer distance, cm.
6. the method according to claim 1 using the continuous pressure measurement data inversion carbon dioxide flooding leading edge of multiple spot, its feature
It is, in step 3, when calculating carbon dioxide additional pressure drop, titanium dioxide is calculated according to actual measurement and theoretical continuous injection production pressure difference
Carbon additional pressure drop, specific formula for calculation are：
In formula,--- carbon dioxide additional pressure drop, atm；
Δps(t) --- theoretical continuous injection production pressure difference, atm；
Δph(t) --- survey continuous injection production pressure difference, atm.
Calculate carbon dioxide it is equivalent involve radius specific formula for calculation be：
In formula：D --- gas injection speed splits a point coefficient, and a line producing well number determines according to corresponding to gas injection well；
R (t) --- carbon dioxide is equivalent to involve radius, cm；
kinj--- the nearly well permeability of gas injection well, μm2, explain to obtain according to the gas injection well single-well transient testing of routine；
hinj--- gas injection well well point effective thickness, cm, obtained according to well log interpretation achievement；
μoil--- underground crude oil viscosity, mPa.s, measured by crude oil PVT experiments；
qgas--- underground gas injection speed, cm3/ s, obtained according to gas injection well dynamic data；
rw--- wellbore radius, cm；
--- carbon dioxide involve in the range of crude oil fifty-fifty descend viscosity, mPa.s, tried to achieve according to following formula：
In formula：--- carbon dioxide underground viscosity, mPa.s；
A --- viscosity mean coefficient.
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| CN110863806A (en) * | 2019-11-28 | 2020-03-06 | 西安石油大学 | Carbon dioxide flooding gas front dynamic change prediction method |
| CN111594113A (en) * | 2019-02-20 | 2020-08-28 | 中国石油化工股份有限公司 | Dynamic inversion method for opening of cracks between tight reservoir wells |
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| US20120152538A1 (en) * | 2010-12-16 | 2012-06-21 | Halliburton Energy Services, Inc. | Compositions and Methods Relating to Establishing Circulation in Stand-Alone-Screens Without Using Washpipes |
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