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Method for evaluating shale oil reservoir water self-absorption oil-displacement effect and oil-displacement time

A shale oil displacement technology, which is applied in the field of evaluating the self-absorption water displacement effect of shale oil reservoirs and determining the best self-absorption water displacement time. Object etc.

Active Publication Date: 2017-06-20
XI'AN PETROLEUM UNIVERSITY
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  • Description
  • Claims
  • Application Information

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Problems solved by technology

At present, shale oil is mainly developed through fractures generated by volume fracturing of horizontal wells. The problem is that fractures provide high-permeability channels, which often make it difficult to recover crude oil in nano-pores with poor seepage capacity.
[0003] The above-mentioned main problems are: (1) The existing research on shale oil mainly includes various evaluation methods of shale oil resources and shale oil reservoirs, fracturing methods of shale oil, shale oil Parameter calculation model, shale oil production or processing method, but the development method of self-imbibtion water flooding shale oil and the determination method of the best self-imbibition time have not been reported; The self-priming oil displacement method of carbonate reservoirs, but the experimental model, experimental means and evaluation methods used are all different from the present invention, and the research objects are very different from the present invention, resulting in existing methods that are not applicable to the present invention Research object; (3) The inventor used nuclear magnetic resonance technology to evaluate the secondary accumulation of oil and gas, the stress sensitivity of the water injection development process, the change of pore throat and the effect of enhanced oil recovery of the medium permeability rock core, but the evaluation object, evaluation The process, the main problem to be solved and the main purpose achieved are quite different from the present invention

Method used

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  • Method for evaluating shale oil reservoir water self-absorption oil-displacement effect and oil-displacement time
  • Method for evaluating shale oil reservoir water self-absorption oil-displacement effect and oil-displacement time
  • Method for evaluating shale oil reservoir water self-absorption oil-displacement effect and oil-displacement time

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Experimental program
Comparison scheme
Effect test

Embodiment 1

[0033] A method for evaluating the self-absorption water flooding effect of shale oil reservoirs and determining the best self-absorption water flooding time includes the following steps:

[0034] Step 1. Configure simulated formation water for the experiment to achieve a salinity of 25,000mg / L;

[0035] Step 2. Put the rock core in a high-pressure saturation device to saturate it with fluorine oil without hydrogen nuclei, and measure the nuclear magnetic resonance T 2 Spectroscopy, Statistical NMR T 2 The area surrounded by the spectrum and the X axis is 764.71;

[0036] Step 3: Put the core in the core holder in the constant temperature box, and continuously inject simulated formation water into both ends of the core at a very low speed of 0.01ml / min to carry out the self-absorption water flooding experiment. The experimental temperature is 40°C, and the ring pressure is 5MPa, NMR T measured after 24 hours of self-absorption water flooding 2 Spectroscopy, Statistical NMR ...

Embodiment 2

[0044] A method for evaluating the self-absorption water flooding effect of shale oil reservoirs and determining the best self-absorption water flooding time includes the following steps:

[0045] Step 1. Configure simulated formation water for the experiment to achieve a salinity of 25,000mg / L;

[0046] Step 2. Put the rock core in a high-pressure saturation device to saturate it with fluorine oil without hydrogen nuclei, and measure the nuclear magnetic resonance T 2 Spectroscopy, Statistical NMR T 2 The area enclosed by the spectrum and the X axis is 370.15;

[0047] Step 3: Put the core in the core holder in the constant temperature box, and continuously inject simulated formation water into both ends of the core at a very low speed of 0.01ml / min to carry out the self-absorption water displacement experiment. The experimental temperature is 10°C, and the ring pressure is 25MPa, NMR T measured after 24 hours of self-absorption water flooding 2 Spectroscopy, Statistical N...

Embodiment 3

[0055] Step 1. Configure simulated formation water for the experiment to achieve a salinity of 25,000mg / L;

[0056] Step 2. Put the rock core in a high-pressure saturation device to saturate it with fluorine oil without hydrogen nuclei, and measure the nuclear magnetic resonance T 2 Spectroscopy, Statistical NMR T 2 The area enclosed by the spectrum and the X-axis is 365.64;

[0057] Step 3: Put the core in the core holder in the constant temperature box, and continuously inject simulated formation water into both ends of the core at a very low speed of 0.01ml / min to carry out the self-absorption water displacement experiment. The experimental temperature is 70°C, and the ring force is 0.1Mpa, NMR T measured after 24 hours of self-absorption water flooding 2 Spectroscopy, Statistical NMR T 2 The area enclosed by the spectrum and the X axis is 453.22;

[0058] Step 4. Repeat step 3. The cores are self-absorbed for water flooding for 48 hours, 72 hours, and 96 hours. After s...

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Abstract

The invention discloses a method for evaluating shale oil reservoir water self-absorption oil-displacement effect and oil-displacement time. The method comprises preparing simulated experimental formation water having a formation water mineralization degree, placing rock cores in saturated hydrogen nucleus-free fluorocarbon oil, detecting nuclear magnetic resonance T2 spectrums, carrying out statistics on an area formed through the nuclear magnetic resonance T2 spectrum and an X axis, carrying out a water self-absorption oil-displacement test on the rock cores, respectively standing the rock cores for different time periods, detecting nuclear magnetic resonance T2 spectrums, carrying out statistics on an area formed through the nuclear magnetic resonance T2 spectrum and the X axis, drawing the nuclear magnetic resonance T2 spectrums of the rock cores stood for different time periods on the same graph, calculating the difference of the areas formed through the nuclear magnetic resonance T2 spectrums in different water self-absorption oil-displacement time periods and the X axis, and determining an increasing rate R of the area formed through the T2 spectrum and the X axis, wherein if R is less than 5%, the corresponding previous self-absorption time is the optimal water self-absorption oil-displacement time. The method can evaluate shale oil capillaceous water self-absorption oil-displacement effects through a nuclear magnetic resonance technology and determine the optimal water self-absorption oil-displacement time.

Description

technical field [0001] The invention relates to the technical field of oil and gas development experiments, in particular to a method for evaluating the self-absorption water displacement effect of shale oil reservoirs and determining the optimum self-absorption water displacement time. Background technique [0002] With the continuous reduction of conventional oil and gas resources, unconventional oil and gas has attracted widespread attention and has become a current research hotspot and difficulty. Shale oil is one of the important unconventional oil and gas resources, because the pore size is mainly nanoscale, the water flooding method of conventional oil reservoirs is not suitable for shale oil reservoirs. At present, shale oil is mainly developed through fractures generated by volume fracturing of horizontal wells. The problem is that fractures provide high-permeability channels, which often make it difficult to recover crude oil in nano-pores with poor seepage capacit...

Claims

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Application Information

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IPC IPC(8): G01N24/08
CPCG01N24/081Y02A90/30
Inventor 高辉张晓王妍何梦卿朱耿博仑李宇
Owner XI'AN PETROLEUM UNIVERSITY
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