威荣深层页岩气井油管最优参数设计研究

doi:10.13809/j.cnki.cn32-1825/te.2022.03.015

Abstract

Abstract:

At the early stage of production, deep shale gas wells in southern Sichuan have sufficient energy. Most of the wells use casing to discharge fluid quickly. When the wellhead pressure drops to the capacity of the pressurized operation or the gas well is difficult to carry fluid, tubing production is run. The tubing installation time typically depends on the wellhead pressure drawdown to the capability of the snubbing unit or the onset time of liquid loading. Tubing depth and diameter are commonly determined based on the production progress according to operators’ field experience. So far, the influence between the tubing installation time and gas well deliverability is still unclear. Based on the well performance monitoring data of 53 times of deep shale gas wells in Southern Sichuan at the casing production stage, the calculation model of wellbore pressure drop and the variation law of wellbore flow pattern are analyzed, besides, the bottom hole flow pressure and critical liquid carrying capacity is also determined the best running time of tubing. In this work, the variation of wellbore pressure drop under different tubing depth is analyzed, and a method to determine the optimal tubing running depth is proposed by aiming at minimizing wellbore pressure drop. Finally, the optimal string size is obtained, and field verification is carried out based on the sensitivity analysis of liquid carrying and pressure loss. The results suggested that the optimum tubing installation time is when wellhead pressure drops to 15~25 MPa. The proper tubing depth is at 70° to 85° of well deviation and the suitable tubing inner diameter is 62 mm. By running tubing in time, the pressure drop rate of the gas well is reduced by 50 %, and the unit pressure drop production is increased by twice times, which effectively guides the tubing design and implementation of deep shale gas horizontal wells in Southern Sichuan.

Key words: tubing diameter, tubing depth, wellbore flow regime, pressure dorp model, deep shale gas

CLC Number:

TE37

Yang DU,Jie NI,Wei LEI, et al. Optimum time of tubing installation in deep shale gas wells of Weirong[J]. Petroleum Reservoir Evaluation and Development, 2022, 12(3): 526-533.

Figures/Tables 14

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References 24

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监测项目	套管内径（mm）	井口压力（MPa）	井口温度（℃）	产气量（10⁴m³/d）	产液量（m³/d）	测点压力（MPa）	测点温度（℃）
最小值	114.3	9.2	30	2.13	9	20.6	123
最大值	118.6	48.0	96	31.29	384	69.5	138
平均值		27.7	55	10.56	116	44.7	132

直井段					斜井段
计算模型	E₁（%）	E₂（%）	E₃（%）	R_RPF	计算模型	E₁（%）	E₂（%）	E₃（%）	R_RPF
ANSARI	11.71	11.82	11.33	0.74	BB	-2.02	3.99	5.33	0
BB	29.71	29.71	19.29	3.00	BJ	-9.03	24.30	29.42	2.65
DR	13.53	13.63	11.50	0.94	DUKLER	-5.97	17.39	20.16	1.64
GRAY	-5.73	7.25	7.78	0	MB	11.62	11.62	5.49	1.34
HB	-6.69	7.61	7.72	0.06	NO SLIP	-2.44	4.68	5.60	0.10
MB	11.91	12.21	10.30	0.70	XIAO	11.75	25.85	27.98	1.94
NO SLIP	-9.71	10.63	9.17	0.44

井段	推荐模型
直井段	GRAY
斜井段	Beggs-Brills
水平段	TAITEL

Optimum time of tubing installation in deep shale gas wells of Weirong

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