Hypercoagulated heavy oil wellbore lifting biological treatment method

A high-condensation oil well and biological treatment technology, applied in chemical instruments and methods, earthwork drilling, wellbore/well components, etc., can solve the problem of not being able to effectively remove high-condensation oil wellbore processing methods that do not involve high-condensation heavy oil wellbore treatment Problems such as waxy components of heavy oil and the inability to lift high-condensation heavy oil have achieved the effects of good field test results, wide application range and strong operability

Pending Publication Date: 2022-05-03
CHINA PETROLEUM & CHEM CORP +1
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  • Summary
  • Abstract
  • Description
  • Claims
  • Application Information

AI Technical Summary

Problems solved by technology

Chinese patent application CN105154050A, the title of the patent application is "a temperature-resistant and salt-resistant heavy oil bio-viscosity reducer and its preparation method", only the colloid and other heavy components in the heavy oil are degraded, and the high-condensation heavy oil cannot be effectively removed The waxy components in the invention, and the invention does not involve the specific implementation process of high pouring oil wellbore treatment
Therefore, the pertinence and operability of this invention are not strong
Chinese patent ZL201210078176.X, titled "A Monitoring Method for Oil Well Microbial Wax Removal and Prevention Operation", is only for the treatment of high-waxy crude oil (low viscosity), but cannot lift high-condensation oil. Invention patents have defects such as pertinence and poor operability

Method used

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  • Hypercoagulated heavy oil wellbore lifting biological treatment method
  • Hypercoagulated heavy oil wellbore lifting biological treatment method
  • Hypercoagulated heavy oil wellbore lifting biological treatment method

Examples

Experimental program
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Effect test

Embodiment 1

[0054] General situation of high pouring heavy oil test well B15 of an oil production plant in Shengli Oilfield: Reservoir temperature is 86°C, formation water salinity is 49554mg / L, crude oil viscosity is 3412.5mPa.s, colloidal asphaltene content is 17.2%, wax content rate is 30.3% , comprehensive water content of 21%. Utilize the method of the present invention to improve this well shaft lifting efficiency, concrete steps are as follows:

[0055] 1. Screening of test wells

[0056] Reservoir temperature is 86°C, salinity of formation water is 49554mg / L, viscosity of crude oil is 3412.5mPa.s, colloidal asphaltene content is 17.2%, wax content is 30.3%, and comprehensive water content is 21%. The screening criteria of the test wells of the present invention are met, so the present invention can be practiced.

[0057] 2. Selection of microbial flora

[0058] Specific steps are as follows:

[0059] Mix 10%V / V~90%V / Vviscosity-reducing strain a (Bacillus subtilis) with 90%V / V~...

Embodiment 2

[0091] General situation of high pouring heavy oil test well B13 in an oil production plant in Shengli Oilfield: Reservoir temperature is 84°C, formation water salinity is 48794mg / L, crude oil viscosity is 3350.5mPa.s, colloidal asphaltene content is 16.2%, wax content rate is 29.3% , comprehensive water content of 25%. Utilize the method of the present invention to improve this well shaft lifting efficiency, concrete steps are as follows:

[0092] 1. Screening of test wells

[0093] Reservoir temperature is 84°C, salinity of formation water is 48794mg / L, viscosity of crude oil is 3350.5mPa.s, colloidal asphaltene content is 16.2%, wax content is 29.3%, and comprehensive water content is 25%. The screening criteria of the test wells of the present invention are met, so the present invention can be practiced.

[0094] 2. Selection of microbial flora

[0095] Specific steps are as follows:

[0096] Mix 10%V / V~90%V / Vviscosity-reducing strain a (Bacillus subtilis) with 90%V / V~...

Embodiment 3

[0128] General situation of high pouring heavy oil test well C15 in an oil production plant in Shengli Oilfield: Reservoir temperature is 80°C, formation water salinity is 46344mg / L, crude oil viscosity is 3222.5mPa.s, colloidal asphaltene content is 16.2%, wax content is 28.5% , comprehensive water content of 28%. Utilize the method of the present invention to improve this well shaft lifting efficiency, concrete steps are as follows:

[0129] 1. Screening of test wells

[0130] Reservoir temperature is 80°C, salinity of formation water is 46344mg / L, viscosity of crude oil is 3222.5mPa.s, colloidal asphaltene content is 16.2%, wax content is 28.5%, and comprehensive water content is 28%. The screening criteria of the test wells of the present invention are met, so the present invention can be practiced.

[0131] 2. Selection of microbial flora

[0132] Specific steps are as follows:

[0133] Mix 10%V / V~90%V / Vviscosity-reducing strain a (Bacillus subtilis) with 90%V / V~10%V / ...

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Abstract

The invention discloses a biological treatment method for shaft lifting of hypercoagulable thickened oil. The biological treatment method comprises the following specific steps: (1) screening a test oil well; (2) optimizing a microbial group; (3) evaluating the dilution capacity of the efficient bacterial group; (4) determining the daily adding amount of the fermentation liquor on site; (5) determining a feeding mode; and (6) field test and effect evaluation. Compared with the prior art, the biological treatment method for shaft lifting of the hypercoagulable heavy oil, disclosed by the invention, has the following advantages: (1) a new thought is provided for shaft lifting of the hypercoagulable heavy oil; (2) the injected bacteria group is harmless to a human body through inspection, does not damage the stratum or pollute the environment, and does not have the problem that the bacteria group is difficult to treat subsequently; (3) the oil reservoir application range is wide; and (4) the technology is simple, the operability is high, the field test effect is good, the electric quantity is saved by more than 600 kilowatt-hours per day, and the thermal well washing time of a single well is saved by more than 3 times per year.

Description

technical field [0001] The invention belongs to the technical field of tertiary oil recovery, and in particular relates to a wellbore lifting biological treatment method for high-condensation heavy oil. Background technique [0002] With the continuous exploitation of global oil resources, the exploitation of high pour point oil has been paid more and more attention. At present, the known high pour point oil resources in China can reach 50×10 8 more than tons. High pour point crude oil has the characteristics of high wax content, high freezing point, and high wax precipitation point, while high pour thick oil is characterized by high viscosity (generally 1000-6000mPa.s) on this basis. Therefore, during the lifting process of the wellbore, the highly pouring heavy oil not only has the characteristics that the high pouring oil is difficult to lift (as the temperature decreases and the gas is precipitated, the surface of the tubing, sucker rod and pump will appear wax deposit...

Claims

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Application Information

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Patent Type & Authority Applications(China)
IPC IPC(8): E21B43/22E21B37/06C09K8/582C09K8/524C09K8/536
CPCE21B43/16E21B37/06C09K8/582C09K8/524C09K8/536
Inventor 徐登霆王静刘方冯云王新高光军郭辽原孙刚正巴燕宋欣
Owner CHINA PETROLEUM & CHEM CORP
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