CN111581585B - Horizontal well thermal diffusion radius calculation method considering wellbore along-path energy loss - Google Patents
Horizontal well thermal diffusion radius calculation method considering wellbore along-path energy loss Download PDFInfo
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- CN111581585B CN111581585B CN202010484346.9A CN202010484346A CN111581585B CN 111581585 B CN111581585 B CN 111581585B CN 202010484346 A CN202010484346 A CN 202010484346A CN 111581585 B CN111581585 B CN 111581585B
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- 238000009792 diffusion process Methods 0.000 title claims abstract description 72
- 238000004364 calculation method Methods 0.000 title claims abstract description 21
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Chemical compound O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 33
- 229920006395 saturated elastomer Polymers 0.000 claims abstract description 31
- 238000000034 method Methods 0.000 claims abstract description 17
- 238000010793 Steam injection (oil industry) Methods 0.000 claims abstract description 13
- 238000002347 injection Methods 0.000 claims description 6
- 239000007924 injection Substances 0.000 claims description 6
- 239000004568 cement Substances 0.000 claims description 4
- 239000000203 mixture Substances 0.000 claims description 4
- 239000011435 rock Substances 0.000 claims description 4
- 230000015572 biosynthetic process Effects 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 238000004458 analytical method Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
Classifications
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- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F17/00—Digital computing or data processing equipment or methods, specially adapted for specific functions
- G06F17/10—Complex mathematical operations
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E10/00—Energy generation through renewable energy sources
- Y02E10/10—Geothermal energy
Abstract
The invention discloses a horizontal well thermal diffusion radius calculation method considering wellbore along-path energy loss in the field of oil-gas field development and research, which mainly comprises the following steps: determining steam injection time, steam injection speed, wellhead pressure and steam dryness; calculating the next pressure along the wellbore direction; calculating the corresponding water vapor saturation temperature under the pressure; calculating heat loss of the well section according to the saturated temperature of the water vapor; calculating the enthalpy of the steam of the well section according to the heat loss; then calculating the enthalpy of the next well section until the enthalpy of the whole shaft in all steam injection time is calculated; calculating the heat diffusion area of each place according to the enthalpy of each place of the shaft; the heat diffusion radius was calculated from the heat diffusion area everywhere. The method fully considers the influence of the energy loss of the shaft along the path, is suitable for calculating the steam throughput thermal diffusion radius of the horizontal well, and improves the accuracy of calculating the diffusion radius, so that the yield of the horizontal well can be accurately predicted.
Description
Technical Field
The invention relates to the field of oil and gas field development and research, in particular to a method for calculating a horizontal well thermal diffusion radius by considering the along-path energy loss of a shaft, which is suitable for determining the size of the horizontal well thermal diffusion radius by considering the along-path energy loss of the shaft.
Background
In the development of a thickened oil field, because the viscosity of the thickened oil is high and the fluidity is poor, the viscosity of the thickened oil needs to be reduced by injecting heat into an oil layer in the development process, and the fluidity of the thickened oil is improved. The early recovery of the thick oil in the oil field mainly uses the vertical well steam huff and puff technology, and the rapid development of the horizontal well technology enables the steam to heat the thick oil in a large area, so that the yield of the thick oil is greatly improved, and the method has become one of important modes for recovering the thick oil reservoir.
In the process of designing a horizontal well steam throughput development scheme, in order to predict the steam throughput yield of the horizontal well, a horizontal well steam throughput analysis model is required to be used for quick calculation, wherein the most important step is to calculate the thermal diffusion radius of steam injected into the horizontal well. Because of the long length of the horizontal well section, steam needs a certain time to flow in the well bore, so the loss of heat energy along the way is not negligible when calculating the heat diffusion radius. The conventional thermal diffusion radius model is over ideal, and the thermal diffusion radius of each part of the horizontal well is considered to be uniform, so that the well bore along-path energy loss is not considered, a certain error exists between the calculated diffusion radius and the actual diffusion radius, and the yield prediction accuracy is directly affected. Therefore, in order to accurately predict the thermal diffusion form in the steam huff and puff process of the horizontal well and improve the steam huff and puff yield prediction precision of the horizontal well, a calculation method of the thermal diffusion radius of the horizontal well considering the energy loss of the shaft along the path is needed to be provided.
Disclosure of Invention
In order to improve the accuracy of calculating the steam huff-puff thermal diffusion radius of the horizontal well and rapidly and accurately predict the steam huff-puff production yield of the horizontal well, the invention provides a method for calculating the thermal diffusion radius of the horizontal well by considering the along-path energy loss of a shaft.
The technical scheme of the invention comprises the following specific steps:
(1) Determining steam injection time t of horizontal well max The vertical section length d of the horizontal well, the horizontal section length L of the horizontal well, the initial time t=0, the wellhead position distance x=0 and the time step n=t/Δt are taken.
(2) Let t=t+Δt, x=0, given the water vapor mass flow i s n Wellhead water vapor pressure P 0 n Wellhead water vapor dryness k.
(3) Inquiring a saturated water and dry saturated steam parameter property table according to wellhead steam pressure to obtain enthalpy h of the dry saturated steam s Enthalpy h of saturated water w Then calculating the enthalpy of wet saturated steam at the time of wellhead n time steps
(4) Let x=x+Δx, using the known saturated steam mixture density ρ m Shaft inclination angle θ, friction loss gradient τ f Mass flow i of water vapor s n Volumetric flow rate q of water vapor s Cross-sectional area of wellbore A p Steam pressure at a well section of a well boreCalculating the steam pressure +.>
(5) Calculating the water vapor saturation temperature at n time steps at the X position of the shaft
(6) By means of the outer diameter r of the horizontal well oil pipe 2 Total heat transfer coefficient U 2 Temperature T at the outer edge of cement sheath h Calculating heat loss in unit time of a well section:
wherein ,is the heat loss per unit time of the interval at time step n at the wellbore X, Δx is the interval length.
(7) According to heat lossCalculating the enthalpy of wet saturated steam at time step n at the well X>If X is not greater than the length d+L of the horizontal well, turning to the step (4); if X is greater than the length d+L of the horizontal well and t is not greater than the steam injection time t max Go to step (2), otherwise go to step (8).
(8) Calculating the heat diffusion areas of different wells Duan De according to the wet saturated steam enthalpy of different shaft positions and time steps after the steam injection is finished, wherein the heat diffusion areas comprise a vertical heat diffusion area A VX Area of heat diffusion in horizontal direction A HX 。
(9) Calculating a thermal diffusion radius from the thermal diffusion area, including a vertical thermal diffusion radius r VX Horizontal thermal diffusion radius r HX 。
The steam pressure calculation method at the time step of n at the shaft X in the step (4) is as follows:
the wet saturated steam enthalpy calculation formula of the n time steps at the shaft X in the step (7) is as follows:
the calculation formula of the heat diffusion area in the step (8) is as follows:
wherein MR Is the volumetric heat capacity of the reservoir, T i Is the original stratum temperature, T A The average stratum temperature of the hot zone after injection is finished, and h is the thickness of the oil layer;
wherein α s Is the thermal diffusivity, lambda of the top and bottom layers s Is the heat conductivity coefficient of the rock at the top and bottom layers.
The thermal diffusion radius calculation formula in the step (9) is as follows:
the invention has the following beneficial effects and advantages:
(1) The well bore along-path energy loss of the horizontal well in the steam injection process is considered, and the prediction precision of the thermal diffusion radius is improved.
(2) The pressure change is divided into a vertical section and a horizontal section for calculation, so that the pressure calculation is more accurate.
(3) The steam diffusion state can be accurately described by considering whether the steam reaches the top and bottom layers.
Drawings
FIG. 1 is a flow chart of the steps of the present invention
FIG. 2 is a schematic view of heat diffusion when steam does not reach the top and bottom layers
FIG. 3 is a schematic view of heat diffusion when vapor reaches the top and bottom layers
Detailed Description
The invention will be further described with reference to the accompanying drawings and examples:
in this embodiment, a method for calculating a thermal diffusion radius of a horizontal well in consideration of energy loss along a wellbore is provided, as shown in fig. 1, and includes the following steps:
(1) Determining steam injection time t of horizontal well max The vertical section length d of the horizontal well, the horizontal section length L of the horizontal well, the initial time t=0d, the wellhead position distance x=0m and the time step n=t/Δt are taken.
Horizontal well gas injection time t in the examples max Horizontal well vertical segment length d=900 m, horizontal well horizontal segment length l=270 m, time step n=24, =24 d.
(2) Let t=t+Δt, x=0m, given the water vapor mass flow i s n Wellhead water vapor pressure P 0 n Wellhead water vapor dryness k.
(3) Inquiring a saturated water and dry saturated steam parameter property table according to wellhead steam pressure to obtain enthalpy h of the dry saturated steam s Enthalpy h of saturated water w Then calculating the enthalpy of wet saturated steam at the time of wellhead n time steps
In the embodiment, the wellhead pressure of the horizontal well is 14.5Mpa, and the enthalpy h of dry saturated steam s Enthalpy h of saturated water =2620 kJ/kg w Well head water vapor dryness k=0.7 to obtain well head wet saturated vapor enthalpy when the well head is n time steps
(4) Let x=x+Δx as shown in fig. 2, using the known saturated water vapor mixture density ρ m Shaft inclination angle θ, friction loss gradient τ f Mass flow i of water vapor s n Volumetric flow rate q of water vapor s Cross-sectional area of wellbore A p Steam pressure at a well section of a well boreCalculating the steam pressure +.>
The steam pressure calculation at time step n at well X is as follows:
in embodiments, when 0<When X is less than or equal to d, the saturatedDensity ρ of water vapor mixture m ＝0.65kg/m 3 Vertical section wellbore inclination θ=30°, friction loss gradient τ f Steam volume flow q=17 Pa/m s ＝1.5×10 -3 m 3 S, cross-sectional area A in the shaft p ＝3×10 -3 m 2 Wellbore section length Δx=10m. When n=10, x=100 m, the water vapor mass flow i s n =1.5 kg/s, and the steam pressure at the well bore is calculated by using a vertical section calculation formulaSimilarly, when n=10 and x=1000m, the water vapor mass flow i s n Steam pressure =1.5 kg/s for the well bore using horizontal segment calculation formula>
(5) Calculating the water vapor saturation temperature at n time steps at the X position of the shaft
For example, when wellbore steam pressure in an embodimentThe saturation temperature of the available water vapor is +.>
＝340.2℃。
(6) By means of the outer diameter r of the horizontal well oil pipe 2 Total heat transfer coefficient U 2 Temperature T at the outer edge of cement sheath h Calculating heat loss in unit time of a well section:
wherein ,is the heat loss per unit time of the interval at time step n at the wellbore X, Δx is the interval length.
In the embodiment, the outer diameter r of the oil pipe 2 =0.0365M, reference is made to the method of Hou et al (Hou Jian. Thermal recovery technique [ M]East ying: china Petroleum university Press, 2013.) to calculate the comprehensive thermal conductivity to be U 2 ＝0.5W/(m 2 Temperature T at the outer edge of the cement sheath h 200 ℃ and length of the well section delta X10 m, according to the calculated heat loss of the well section in unit time of n time steps at the well bore X
(7) According to heat lossCalculating the enthalpy of wet saturated steam at time step n at the well X>If X is not greater than the length d+L of the horizontal well, turning to the step (4); if X is greater than the length d+L of the horizontal well and t is not greater than the steam injection time t max Turning to step (2), otherwise turning to step (8);
the wet saturated steam enthalpy for n time steps at wellbore X is calculated as follows:
for example, n=10, x=900 m saturated steam enthalpy
(8) As shown in FIG. 3, the heat diffusion area of different wells Duan De is calculated according to the wet saturated steam enthalpy of different well shaft positions and time steps after the steam injection is finished, including vertical heat expansionArea of dispersion A VX Area of heat diffusion in horizontal direction A HX ；
The thermal diffusion area calculation formula is as follows:
wherein MR Is the volumetric heat capacity of the reservoir, T i Is the original stratum temperature, T A The average stratum temperature of the hot zone after injection is finished, and h is the thickness of the oil layer;
wherein α s Is the thermal diffusivity, lambda of the top and bottom layers s Is the heat conductivity coefficient of the rock at the top and bottom layers.
Whether the steam reaches the top and bottom layers can be judged according to whether the oil reservoir in the whole horizontal well region can be heated to the average stratum temperature of the stratum or not by the injected heat. Such as when based on the volumetric heat capacity M of the reservoir R ＝2277kJ/(m 3 Temperature T of original formation i Temperature of the hot zone average formation after injection T =60℃ A When the temperature is 180 ℃ and the oil layer thickness h=10m, steam does not reach the top and bottom layers, and the vertical diffusion area A at the initial position of the horizontal section, namely X=900 m, is calculated VX ＝55.3m 2 Area A of diffusion in horizontal direction HX ＝0m 2 The method comprises the steps of carrying out a first treatment on the surface of the If the average formation temperature T of the hot zone after injection is finished A When 110 ℃, the vapor reaches the top and bottom layers, according to the thermal diffusivity α of the top and bottom layers s ＝0.0045m 2 And/h, the heat conductivity coefficient lambda of the rock at the top and bottom layers s ＝2.56W/(m 3 Calculating X=900 m vertical diffusion area A at the initial position of the horizontal section VX ＝78.5m 2 Area A of diffusion in horizontal direction HX ＝254.6m 2 (Note: different locations are inconsistent in thermal diffusion area, the closer to the wellhead, the larger the thermal diffusion area, examplesOnly the heat diffusion area calculation method at a certain position is given, and other positions may be so pushed).
(9) Calculating a thermal diffusion radius from the thermal diffusion area, including a vertical thermal diffusion radius r VX Horizontal thermal diffusion radius r HX 。
The thermal diffusion radius calculation formula is as follows:
the vertical diffusion radius is obtained when the steam does not reach the top and bottom layers when the initial part of the horizontal segment is X=900 mDiffusion radius r in horizontal direction HX =0m; when the steam reaches the top and bottom layers, the vertical diffusion radius is obtained>Diffusion radius in horizontal direction-> (note: the thermal diffusion radius is not uniform at different locations, the closer to the wellhead, the larger the thermal diffusion radius, the embodiment only gives a thermal diffusion radius calculation method at a certain location, and other locations can be similarly inferred).
Claims (5)
1. A method for calculating a horizontal well thermal diffusion radius by considering the energy loss of a shaft along the path is characterized by comprising the following steps:
(1) Determining steam injection time t of horizontal well max Taking the initial time t=0, taking the wellhead position distance as x=0, and taking the time step n=t/Δt;
(2) Let t=t+Δt, x=0, given the water vapor mass flow i s n Wellhead water vapor pressure P 0 n Wellhead water vapor dryness k;
(3) Inquiring a saturated water and dry saturated steam parameter property table according to wellhead steam pressure to obtain enthalpy h of the dry saturated steam s Enthalpy h of saturated water w Then calculating the enthalpy of wet saturated steam at the time of wellhead n time steps
(4) Let x=x+Δx, using the known saturated steam mixture density ρ m Shaft inclination angle θ, friction loss gradient τ f Mass flow i of water vapor s n Volumetric flow rate q of water vapor s Cross-sectional area of wellbore A p Steam pressure at a well section of a well boreCalculating the steam pressure +.>
(5) Calculating the water vapor saturation temperature at n time steps at the X position of the shaft
(6) By means of the outer diameter r of the horizontal well oil pipe 2 Total heat transfer coefficient U 2 Temperature T at the outer edge of cement sheath h Calculating heat loss in unit time of a well section:
wherein ,is the heat loss in the unit time of the well section in the n time steps at the position of the well bore X, and delta X is the length of the well section;
(7) According to heat lossCalculating the enthalpy of wet saturated steam at time step n at the well X>If X+DeltaX is not greater than the length d+L of the horizontal well, turning to the step (4); if X+DeltaX is greater than the length d+L of the horizontal well and t+Deltat is not greater than the steam injection time t max Turning to step (2), otherwise turning to step (8);
(8) Calculating the heat diffusion areas of different wells Duan De according to the wet saturated steam enthalpy of different shaft positions and time steps after the steam injection is finished, wherein the heat diffusion areas comprise a vertical heat diffusion area A VX Area of heat diffusion in horizontal direction A HX ；
(9) Calculating a thermal diffusion radius from the thermal diffusion area, including a vertical thermal diffusion radius r VX Horizontal thermal diffusion radius r HX 。
2. A method for calculating a thermal diffusion radius of a horizontal well taking into account energy loss along the well bore as set forth in claim 1, wherein the steam pressure calculation method at the time step n at the well bore X in said step (4) is as follows:
3. a method for calculating a thermal diffusion radius of a horizontal well taking into account energy loss along the well bore as set forth in claim 1, wherein the wet saturated steam enthalpy at the well bore X in said step (7) for n time steps is calculated as follows:
4. a method for calculating a thermal diffusion radius of a horizontal well taking into account energy loss along the well bore as set forth in claim 1, wherein the thermal diffusion area calculation formula in said step (8) is as follows:
wherein MR Is the volumetric heat capacity of the reservoir, T i Is the original stratum temperature, T A The average stratum temperature of the hot zone after injection is finished, and h is the thickness of the oil layer;
wherein α s Is the thermal diffusivity, lambda of the top and bottom layers s Is the heat conductivity coefficient of the rock at the top and bottom layers.
5. A method for calculating a thermal diffusion radius of a horizontal well taking into account energy loss along the well bore as set forth in claim 1, wherein the thermal diffusion radius calculation formula in said step (9) is as follows:
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| CN103867174A (en) * | 2014-02-26 | 2014-06-18 | 中国石油天然气股份有限公司 | Method and system for analyzing steam suction condition of thick oil horizontal well |
| CN109033565A (en) * | 2018-07-06 | 2018-12-18 | 中国石油天然气股份有限公司 | A kind of horizontal wells in heavy oil reservoir superheated steam is handled up Dynamic Productivity Calculation prediction technique |
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| CN103867174A (en) * | 2014-02-26 | 2014-06-18 | 中国石油天然气股份有限公司 | Method and system for analyzing steam suction condition of thick oil horizontal well |
| CN109033565A (en) * | 2018-07-06 | 2018-12-18 | 中国石油天然气股份有限公司 | A kind of horizontal wells in heavy oil reservoir superheated steam is handled up Dynamic Productivity Calculation prediction technique |
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| 水平井蒸汽吞吐加热半径和地层参数计算模型;刘春泽;程林松;刘洋;庞占喜;;石油学报;第29卷(第01期);101-105 * |
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