RU2543848C1 - Development method of heavy oil or bitumen mine field with controlled product extraction from horizontal wells - Google Patents

Abstract

FIELD: oil and gas industry.

SUBSTANCE: development method of heavy oil or bitumen mine field with controlled production extraction includes construction of the top injector and bottom producer with horizontal sections placed one above the other, injection of heat carrier through the horizontal injector with bed heating by creation of steam chamber and extraction of the product through the bottom producer. Thermograms of steam chamber are taken, the chamber's warm-up state is analysed for uniform heating and available temperature peaks, and considering the obtained thermograms uniform heating of steam chamber is performed by changing zones of product extraction. Before start-up of extraction with permanent taking of thermograms heat carrier is injected to the below horizontal well until the layer between wells is heated. Thereafter thermograms are taken along horizontal boreholes of both wells with identification of interval with maximum temperature between the wells. Then measurement instruments are removed, heat carrier in injected to the injector and pump is run in to the above interval in the producer, product is produced by the pump till pressure communication is set between the wells. The pump is removed from the producer, a pump with fibre-optical cable is run in to the well in order to control thermogram along the whole length of producer and monitor pump movement to less heated intervals in process of oil or bitumen production.

EFFECT: usage of this method allows increase in oil recovery factor and open flow potential due to even heating of the steam chamber using standard equipment.

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Description

The invention relates to the oil industry, in particular to thermal methods for producing highly viscous oil or bitumen.

A known method of recovery of the operating state of an oil and gas producing well with horizontal and / or subhorizontal completion during operation and a technological complex for implementing the method (US Pat. RF No. 2482268, IPC E21B 47/10, E21B 21/25, E21B 37/00, publ. 20.05. 2013). The known method includes three stages, the first of which carry out geophysical measurements of the well parameters, which determine the profile of the inflow of the studied section of the well with the allocation of "idle" intervals. At the second stage, the sections of the well are washed from technogenic liquids at “non-working” intervals. At the third stage, control measurements of the geophysical parameters of the well are carried out with the determination of the qualitative and quantitative characteristics of the flow rate of “idle” intervals.

The disadvantages of this method are the multiplicity and high cost of geophysical exploration of the well.

The closest in technical essence to the proposed method is a method of developing heavy oil or bitumen deposits with regulation of the selection of well production (US Pat. RF No. 2413068, IPC E21B 43/24, publ. 02.27.2011), including the construction of an upper injection well and lower production well with horizontal sections located one above the other, pumping coolant through a horizontal injection well with heating the formation by creating a steam chamber and taking products through a horizontal production well, m thermogram steam chamber, analysis of warm-uniform heating temperature and the presence of peaks and considering the obtained thermograms implementation uniform heating of the vapor chamber, changing the output selection area. Horizontal sections of the wells are equipped with filters. Inside the filter of the producing well, a pump shank is provided with inlet openings dividing the filter into selection zones. The shank is equipped inside with a rod, the inner space of which is communicated with the pump inlet. The pump descends on a pipe string, which at the mouth is equipped with a double-acting jack. The space between the stem and the shank between the inlet openings of the shank is hermetically separated before the descent ring inserts.

The disadvantages of this method are the use of non-serial equipment for regulating the selection of products from the well and the high cost of its manufacture.

The technical objectives of the proposed method are to reduce the cost of research and technology for regulating the selection of products from horizontal wells during the development of high-viscosity oil or bitumen deposits, increasing the oil production rate using standard equipment.

The stated technical problems are solved by the method of developing an oil or bitumen field with regulation of the selection of well production, including the construction of an upper injection well and a lower production well with horizontal sections located one above the other, injection of a heat carrier through a horizontal injection well with formation heating by creating a steam chamber and production selection through horizontal production well, in which thermograms of the steam chamber are taken, the state of its prog Eva on the uniformity of heating and the presence of temperature peaks and taking into account the obtained thermograms carry out uniform heating of the steam chamber, changing the zones of production selection.

What is new is that before the start of the selection with constant removal of the thermogram, the coolant is also pumped into the lower horizontal well until the layer of the field is heated between the wells, after which the thermograms are taken along the horizontal boreholes of both wells, determining the interval with the maximum temperature between the wells, then the measuring instruments are removed and pumped coolant into the injection well and lower the pump into a given interval of the producing well, produce products by the pump until a hydrodynamic coupling and between boreholes, remove the pump from the production well, it is lowered into the pump fiber optic cable for controlling thermogram throughout the length of the production well and a pump for controlled movement in at least warmed intervals during oil or bitumen.

The drawing shows a horizontal arrangement of the injection and production wells.

The method is implemented as follows.

The upper horizontal well 1 is drilled, according to updated geological data, a horizontal production well 2 is located 5-8 m below it.

Columns of tubing 3, 4 are lowered to a certain length in wells 1, 2. Steam is pumped into injection 1 and production 2 wells by tubing 3 and 4 in an amount sufficient to warm the layer of the field between wells 1, 2, and stop steam injection and for 5-7 days the wells are kept on thermocapillary impregnation, after which the temperature profiles of the injectivity of each well 1, 2 are measured on a flexible pipe (not specified) through a tubing 3, 4 with an independent device (not specified). The device is removed. Based on the analysis and comparison of thermograms for the production well 2, the most heated section 5 between the wells is selected. From the producing well 2, the tubing 4 is lifted and the pump (not specified) is lowered to a depth corresponding to the heated section 5, and fluid withdrawal is started. Steam injection is resumed in injection well 1. After obtaining a hydrodynamic connection between the wells, which is confirmed by an increase in the temperature of the products at the wellhead 2 and physico-chemical analyzes, the pump is lifted and lowered by an optical fiber cable in a flexible pipe 6 over the entire length of the well, then the pump is lowered into a less warmed area (not specified) (not specified) with an adjustable drive (not specified), the products are selected until a hydrodynamic connection is obtained in the selection interval, after which the pump is moved to another less warmed area (not specified).

An example of a specific implementation of the method.

A horizontal injection well 1 with a horizontal part length of 540 m was drilled at a section of the Ashalchinskoye field with an average oil viscosity of 25,000 mPa · s, permeability of 2.6 μm ² , porosity of 30%, and a thickness of 18 m. Below, we drilled a horizontal section of well 1 by 7 m 7 production well 2 with a horizontal section length of 560 m. The tubing 3, 4 were launched into each of the wells to a length of 350 and 360 m, respectively. 3,600 tons of steam were injected into injection well 1 and 2,800 tons into production well 2.

After stopping the steam injection, leveling and lowering the bottomhole temperature after seven days in the producing and injection wells through tubing 3, 4, a stand-alone device on a flexible pipe removed the temperature profile of the injectivity of each of the wells. The most warmed up zone 5 was identified, tubing 4 was lifted from the production well, then the installation of an electric centrifugal pump (ESP) was lowered to the selected heated section 5 (not specified). In injection well 1 resumed the injection of steam in the amount of 80 tons / day. By launching the ESP, production well 2 was put to fluid selection with control over the dynamic levels and temperature at the pump intake, and the fluid was increased to stabilize the dynamic level and obtain a hydrodynamic connection between the wells. They lifted the pump and lowered the fiber-optic cable in a flexible pipe 6 to the length of the well, then, in a less warmed area (not indicated), they lowered the ESP with a frequency-controlled drive and an automated thermomanometric system (TMS) (not specified). In injection well 1 resumed the injection of steam in the amount of 90 tons / day. After the site was heated to a high temperature, which was recorded via an optical fiber cable, the pump was moved to a less heated area and the selection was continued. The average well production rate was 38 tons / day.

For comparison, the option was adopted using two parallel drilled (one above the other) horizontal wells with a horizontal bore length: injection - 590 m, production - 580 m. The depth of the pump descent was chosen without taking into account the most heated section, the regulation of fluid selection and change of sampling intervals were not were produced. The results showed that the effectiveness of the proposed method is higher: the maximum oil production rate was 38 tons / day versus 21 tons / day.

Using this method allows for uniform heating of the steam chamber, which helps to increase the flow rate by 20-50%, increase the oil recovery coefficient, reduce the cost of the technology for regulating the selection of products from horizontal wells through the use of standard equipment.

Claims (1)

A method of developing an oil or bitumen field with regulation of the selection of production wells, including the construction of an upper injection well and a lower production well with horizontal sections located one above the other, pumping a coolant through a horizontal injection well with heating the formation by creating a steam chamber and selecting production through a horizontal producing well, in which thermograms of the steam chamber are taken, the state of its heating for uniformity of heating and the presence of pace are analyzed The temperature peaks and taking into account the obtained thermograms carry out uniform heating of the steam chamber, changing the product sampling zones, characterized in that before the start of the selection with constant removal of the thermogram, the coolant is also pumped into the lower horizontal well until the layer of the deposit is warmed up between the wells, and then the thermograms are taken along horizontal trunks both wells, determining the interval with the maximum temperature between the wells, then remove the measuring instruments, pump the coolant into the injection the well and lower the pump to a given interval of the producing well, produce products by the pump until a hydrodynamic connection between the wells appears, remove the pump from the producing well, lower the pump with fiber-optic cable into it to control the thermogram along the entire length of the producing well and to control the pump to move less heated intervals during oil or bitumen production.

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