Oil-displacing agent and oil-displacing method for enhancing recovery ratio of high-temperature, high-salinity and high-hardness reservoir crude oil

A high-temperature, high-salt, oil-displacing agent technology, applied in chemical instruments and methods, production fluids, earthwork drilling and production, etc., can solve problems such as poor temperature resistance, salt resistance, hardness resistance, high concentration, and low oil displacement efficiency. Achieve excellent performance, improve comprehensive performance, and good compatibility

Active Publication Date: 2013-08-21
CHINA UNIV OF PETROLEUM (EAST CHINA)
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  • Summary
  • Abstract
  • Description
  • Claims
  • Application Information

AI Technical Summary

Problems solved by technology

[0006] The technical problem to be solved by the present invention is that the oil displacement agent used in the existing enhanced oil recovery method has the problems of po

Method used

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  • Oil-displacing agent and oil-displacing method for enhancing recovery ratio of high-temperature, high-salinity and high-hardness reservoir crude oil
  • Oil-displacing agent and oil-displacing method for enhancing recovery ratio of high-temperature, high-salinity and high-hardness reservoir crude oil
  • Oil-displacing agent and oil-displacing method for enhancing recovery ratio of high-temperature, high-salinity and high-hardness reservoir crude oil

Examples

Experimental program
Comparison scheme
Effect test

Embodiment 1

[0031] [Example 1] compatibility experiment

[0032] The components of the oil displacing agent are as follows:

[0033] Amine oxide type amphoteric surfactant I, in formula (1), R 1 for C 12 h 25 -, R 2 for -CH 2 -CH 2- .

[0034] Alkylphenol polyoxyethylene ether carboxylate I, in formula (2), R 3 for C 9 h 19- , n=10, M is sodium.

[0035] Water is salinity 12×10 4 mg / L, Ca 2+ +Mg 2+ The total amount of formation water is 8500mg / L.

[0036] The proportion of oil displacing agent is as follows:

[0037] Oil displacement agent a: amine oxide type amphoteric surfactant 10.05wt%, alkylphenol polyoxyethylene ether carboxylate 10.15wt%, surplus formation water;

[0038] Oil displacement agent b: amine oxide type amphoteric surfactant 10.07wt%, alkylphenol polyoxyethylene ether carboxylate 10.20wt%, surplus formation water.

[0039] Oil displacement agent preparation method:

[0040] Add the amine oxide type amphoteric surfactant I and the alkylphenol polyoxyethyl...

Embodiment 2

[0042] [Example 2] Interfacial tension experiment

[0043] The oil displacement agent was prepared as described in Example 1.

[0044] The interfacial tension between the oil displacement agent and dehydrated and degassed crude oil (viscosity 0.378mPa·s, density 0.825g / mL at 110°C) was measured under reservoir conditions. The experimental results are shown in Table 1 and figure 2 . The interfacial tension was measured by a TX500 spinning drop interfacial tensiometer produced by the University of Texas. From Table 1 and figure 2 It can be seen that the interface of the compound system of 0.05wt%~0.07wt% amine oxide type amphoteric surfactant (A) and 0.15wt%~0.20wt% alkylphenol polyoxyethylene ether carboxylate (B) The tension can be as low as 1.7×10 -3 mN / m.

[0045] Table 1 The interfacial tension of the compound system of amine oxide type amphoteric surfactant (A) and alkylphenol polyoxyethylene ether carboxylate (B)

[0046]

[0047]

Embodiment 3

[0048] [Example 3] thermal stability experiment

[0049] The components of the oil displacing agent are as follows:

[0050] Amine oxide type amphoteric surfactant II, in formula (1), R 1 for C 14 h 29 -, R 2 for -CH 2- CH 2- CH 2- .

[0051] Alkylphenol polyoxyethylene ether carboxylate II, in formula (2), R 3 for C 16 h 33- , n=15, M is sodium.

[0052] Water is 12×10 4 mg / L, Ca 2+ +Mg 2+ The total amount of formation water is 8500mg / L.

[0053] Use the formation water to prepare the oil displacement agent solution of the amine oxide type amphoteric surfactant II and the alkylphenol polyoxyethylene ether carboxylate II. In terms of mass percentage, the amine oxide type amphoteric surfactant II, alkyl The ratio of phenol polyoxyethylene ether carboxylate II to formation water is 0.05wt%:0.15wt%:99.80wt%. The oil-displacing agent solution is injected into the ampoule and sealed, packed into a high-temperature aging tank, and placed in a constant temperature dry...

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Abstract

The invention relates to an oil-displacing agent and an oil-displacing method for enhancing the recovery ratio of high-temperature, high-salinity and high-hardness reservoir crude oil. The oil-displacing agent is composed of the following components in percentage by mass: A, 0.05-0.07% of an amine oxide type amphoteric surfactant; B, 0.15-0.20% of alkylphenol ethoxylate carboxylate; and C, the balance of water. The oil-displacing method disclosed by the invention is implemented through injecting the oil-displacing agent into a natural core subjected to oil-displacing under the conditions that the oil reservoir temperature is 100-120 DEG C, the total salinity of formation water is (10-15)*10<4> mg/L, and the amount of calcium-magnesium divalent metal ions is 7000-10000 mg/L, so that residual oil is in contact with the oil-displacing agent, and then the residual oil is fully displaced. The oil-displacing agent provided by the invention reaches the magnitude order of 10<-3> mN/m under the condition of high-temperature, high-salinity and high-hardness salt reservoirs, and the interfacial tension still can be maintained in an ultra-low interfacial tension state after the oil-displacing agent is aged for a long time under the condition of oil reservoirs, therefore, the oil-displacing agent is applied to the tertiary oil recovery production of oil fields.

Description

technical field [0001] The invention relates to an oil displacement method for improving the recovery rate of crude oil in a high-temperature, high-salt, high-hardness reservoir, in particular to the application of an amphoteric surfactant in tertiary oil recovery, and belongs to the technical field of oil recovery. Background technique [0002] As the early-developed oilfields have entered the "double high" stage of high water cut and high recovery, water flooding is becoming more and more difficult to stabilize production, and the development situation is severe; domestic demand is increasing, production is declining, and oil resources are seriously insufficient. The exploitation of hard-to-produce reserves in harsh reservoirs such as high-temperature and high-salt reservoirs, heavy oil reservoirs, and low-permeability reservoirs is becoming increasingly urgent. my country's Huabei Oilfield, Dagang Oilfield, Zhongyuan Oilfield, Tarim Oilfield and other oilfields all have h...

Claims

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Application Information

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IPC IPC(8): C09K8/584E21B43/22
Inventor 戴彩丽赵健慧由庆赵明伟闫立鹏方吉超赵光赵福麟
Owner CHINA UNIV OF PETROLEUM (EAST CHINA)
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