通道压裂过程中主裂缝支撑剂铺置影响因素实验研究

Abstract

Abstract:

The polymer is easily trapped in the gap between the proppant particles, so the conventional hydraulic fracturing technology of the uniform sand production has limitation for the transformation of the low permeability, ultra-low permeability and shale gas reservoirs. The channel hydraulic fracturing technology can effectively increase the oil and gas production by forming a high diversion channel by non-uniform sand deposition. The effects of channel fracturing technique are mainly determined by the channel size of the formed sand embankment. By the similarity criterion, we established the experimental method of visual simulation system of channel fracturing to systematically analyzed the influence of the fracturing fluid viscosity, proppant concentration, fiber addition, pore arrangement, pulse time and construction displacement on the proppant placement pattern and channel ratio. Then we used the methods of the partial least squares regression and the importance of variable projection to analyze the influence degree of various factors on the channel rate. Under the experimental conditions, it is indicated that when the injecting volume is 4 ~ 6 m ³/min and the viscosity of fracturing fluid is 150 ~ 250 mPa·s, the concentration of proppant is lower, the concentration of fiber is higher, the pulse time is shorter, the perforation methods is more, and the higher viscosity is better. By means of partial least squares regression, importance analysis of variable projection, and Pearson product-moment correlation coefficient, the influence degree of each channel rate is in a descending order as: viscosity of fracturing fluid > perforation methods > pulse time > concentration of fracturing proppant > concentration of fiber > injecting volume.

Key words: channel fracturing, channel ratio, visualization, partial least squares regression, variable projection

CLC Number:

TE377

Pingli Liu,Zhenming Li,Yuchun Song, et al. Experimental study on influence factors of proppant placement in main fracture of channel fracturing process[J]. Reservoir Evaluation and Development, 2018, 8(5): 42-47.

Figures/Tables 12

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References 18

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编号	排量/ （m³·h^-1）	黏度/（mPa·s）	支撑剂浓度/（kg·m^-3）	脉冲时间/s	纤维浓度/（kg·m^-3）	射孔簇数/簇	通道率,%
1	1.2	30	360	15	5	3	9.45
2	1.2	50	360	15	5	3	15.04
3	1.2	70	360	15	5	3	20.13
4	1.2	100	360	15	5	3	28.89
5	1.2	150	360	15	5	3	19.07
6	1.2	200	360	15	5	3	24.88
7	1.2	240	360	15	5	3	27.24
8	1.2	270	360	15	5	3	21.43
9	1.2	300	360	15	5	3	11.13
10	1.2	200	360	15	5	1	10.75
11	1.2	200	360	15	5	2	19.15
12	1.2	200	360	15	5	4	36.79
13	1.2	200	360	15	5	5	43.81
14	1.2	200	360	15	1	3	11.23
15	1.2	200	360	15	3	3	18.25
16	1.2	200	360	15	5	3	24.88
17	1.2	200	360	15	6	3	22.18
18	1.2	200	360	15	5	3	24.88
19	1.2	200	360	20	5	3	20.15
20	1.2	200	360	25	5	3	14.31
21	1.2	200	360	10	5	3	42.34
22	1.2	200	60	15	5	5	68.33
23	1.8	200	200	15	5	5	49.96
24	1.8	200	360	15	5	5	43.81
25	1.8	200	420	15	5	5	30.13
26	1.8	200	600	15	5	5	24.67
27	1.8	200	720	15	5	5	17.71
28	1.8	200	900	15	5	5	12.57
29	1.8	200	1 020	15	5	5	9.72
30	1.8	200	1 260	15	5	5	2.45
31	0.9	200	200	15	5	3	16.45
32	2.4	200	200	15	5	3	32.55
33	3.0	200	200	15	5	3	11.32

R_ab	X₁	X₂	X₃	X₄	X₅	X₆
X₁	1	-0.56	-0.449	-0.688	-0.646	-0.777
X₂		1	-0.083	-0.106	0.056	-0.05
X₃			1	0.591	-0.861	-0.519
X₄				1	-0.527	-0.962
X₅					1	-0.548
X₆						1

Experimental study on influence factors of proppant placement in main fracture of channel fracturing process

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References 18

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