RU2000116191A - METHOD FOR DEVELOPING DEPOSITS OF HIGH-VISCOUS OIL - Google Patents
METHOD FOR DEVELOPING DEPOSITS OF HIGH-VISCOUS OILInfo
- Publication number
- RU2000116191A RU2000116191A RU2000116191/03A RU2000116191A RU2000116191A RU 2000116191 A RU2000116191 A RU 2000116191A RU 2000116191/03 A RU2000116191/03 A RU 2000116191/03A RU 2000116191 A RU2000116191 A RU 2000116191A RU 2000116191 A RU2000116191 A RU 2000116191A
- Authority
- RU
- Russia
- Prior art keywords
- coolant
- packer
- kcal
- uninsulated
- tubing
- Prior art date
Links
- 239000002826 coolant Substances 0.000 claims 12
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims 8
- 238000002347 injection Methods 0.000 claims 5
- 239000007924 injection Substances 0.000 claims 5
- 238000005553 drilling Methods 0.000 claims 1
- 238000005086 pumping Methods 0.000 claims 1
Claims (2)
где qn - расход теплоносителя по колонне НКТ, кг/ч;
h'' - энтальпия теплоносителя на устье нагнетательной скважины, ккал/кг;
h' - энтальпия теплоносителя в разрабатываемом объекте ниже пакера, ккал/кг,
h' = (tк2-tн)•Св;
tк1 - температура воды, закачиваемой через затрубное пространство в верхней части объекта (выше пакера), oС;
tк2 - температура теплоносителя в нижней части объекта (ниже пакера), oС;
tн - начальная температура холодной воды на устье скважины, oС;
Св - средняя удельная теплоемкость воды, ккал/кг•град.1. A method of developing a reservoir of high-viscosity oil, including drilling injection and producing wells, equipping the injection well with a tubing string and heat-resistant packer, pumping coolant into the injection well and extracting oil from the producing well, characterized in that the upper part of the tubing string they are composed of thermally insulated pipes, and the lower part is left uninsulated above the level of the developed object, a heat-resistant packer is installed in the middle of the developed object, then black of tubing coolant is pumped into the lower part of the object (below the packer), and through the annulus cold water is pumped into the top of the object (above the packer), and the flow of cold water is determined by the formula
where q n is the coolant flow through the tubing string, kg / h;
h '' is the coolant enthalpy at the mouth of the injection well, kcal / kg;
h 'is the enthalpy of the coolant in the developed object below the packer, kcal / kg,
h '= (t k2 -t n ) • C in ;
t k1 - temperature of water pumped through the annulus in the upper part of the object (above the packer), o С;
t K2 - temperature of the coolant in the lower part of the object (below the packer), o С;
t n - the initial temperature of cold water at the wellhead, o C;
C in - the average specific heat of water, kcal / kg • deg.
где qn - расход теплоносителя по колонне НКТ, кг/ч;
h'' - энтальпия теплоносителя на устье нагнетательной скважины, ккал/кг;
h' - энтальпия теплоносителя в разрабатываемом объекте ниже пакера, ккал/кг;
D - диаметр неизолированной колонны;
К - коэффициент теплопередачи от теплоносителя к холодной воде, ккал/м2•час•град;
θср - средняя разность температур в верхней и нижней части неизолированного участка НКТ, θср = θв-θн, °C;
θв - разность температур между теплоносителем и водой в верхней части неизолированной НКТ, oС;
θн - разность температур между теплоносителем и водой в нижней части неизолированной НКТ (в районе пакера), oС.2. The method according to p. 1, characterized in that the length of the uninsulated part of the tubing string is determined by the formula
where q n is the coolant flow through the tubing string, kg / h;
h '' is the coolant enthalpy at the mouth of the injection well, kcal / kg;
h 'is the coolant enthalpy in the developed object below the packer, kcal / kg;
D is the diameter of the uninsulated column;
K is the heat transfer coefficient from the coolant to cold water, kcal / m 2 • hour • hail;
θ cf is the average temperature difference in the upper and lower parts of the uninsulated tubing section, θ cf = θ in -θ n , ° C;
θ in - the temperature difference between the coolant and water in the upper part of the uninsulated tubing, o C;
θ n - the temperature difference between the coolant and water in the lower part of the uninsulated tubing (in the area of the packer), o C.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
RU2000116191/03A RU2187630C2 (en) | 2000-06-19 | 2000-06-19 | Method of development of high-viscosity oil pool |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
RU2000116191/03A RU2187630C2 (en) | 2000-06-19 | 2000-06-19 | Method of development of high-viscosity oil pool |
Publications (2)
Publication Number | Publication Date |
---|---|
RU2000116191A true RU2000116191A (en) | 2002-06-20 |
RU2187630C2 RU2187630C2 (en) | 2002-08-20 |
Family
ID=20236559
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
RU2000116191/03A RU2187630C2 (en) | 2000-06-19 | 2000-06-19 | Method of development of high-viscosity oil pool |
Country Status (1)
Country | Link |
---|---|
RU (1) | RU2187630C2 (en) |
Families Citing this family (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN102562014B (en) * | 2010-12-31 | 2014-07-02 | 中国石油天然气股份有限公司 | High solidifying point crude oil exploiting device and high solidifying point crude oil exploiting method |
CA2803428C (en) * | 2012-01-31 | 2017-03-07 | World Energy Systems Incorporated | Method and system for controlling wellbore production temperature |
RU2688821C1 (en) * | 2018-07-13 | 2019-05-22 | Ильдар Зафирович Денисламов | Multifunctional well for extraction of high-viscosity oil |
-
2000
- 2000-06-19 RU RU2000116191/03A patent/RU2187630C2/en not_active IP Right Cessation
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