川西海相长水平井白油基钻井液技术研究与应用

韩子轩; 韩秀贞; 王显光; 李大奇; 黄河淳; 陈晓飞

doi:10.12358/j.issn.1001-5620.2025.04.010

川西海相长水平井白油基钻井液技术研究与应用

doi: 10.12358/j.issn.1001-5620.2025.04.010

韩子轩^{1, 2, 3,},
韩秀贞^{1, 2, 3},
王显光^{1, 2, 3},
李大奇^{1, 2, 3},
黄河淳⁴,
陈晓飞^{1, 2, 3}

1.
国家能源碳酸盐岩油气重点实验室, 北京102206
2.
中国石化超深井钻井工程技术重点实验室, 北京102206
3.
中石化石油工程技术研究院有限公司, 北京102206
4.
中国石化西南油气分公司石油工程技术研究院, 四川德阳 618000

基金项目: 深地国家科技重大专项项目"重点地区深部热能探测评价"（2024ZD1003600）。

详细信息

作者简介:
韩子轩，1982年生，博士，现从事井壁稳定与钻井液技术研究工作。E-mail：hanzx.sripe@sinopec.com

中图分类号: TE254.3
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- 文章访问数: 23
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- 被引次数: 0
出版历程
- 收稿日期: 2025-04-06
- 修回日期: 2025-05-02
- 刊出日期: 2025-07-31

Research and Application of White Oil-Based Drilling Fluid Technology for Long Horizontal Wells in Western Sichuan

HAN Zixuan^{1, 2, 3
,},
HAN Xiuzhen^{1, 2, 3},
WANG Xianguang^{1, 2, 3},
LI Daqi^{1, 2, 3},
HUANG Hechun⁴,
CHEN Xiaofei^{1, 2, 3}

1.
State Energy Key Laboratory for Carbonate Oil and Gas, Beijing 102206
2.
Sinopec Key Laboratory of Ultra-Deep Well Drilling, Beijing 102206
3.
Sinopec Research Institute of Petroleum Engineering Co., Ltd, Beijing 102206
4.
Research Institute of Petroleum Engineering Technology, Southwest Oil and Gas Company, Sinopec, Deyang, Sichuan 618000

摘要

摘要: 为解决川西海相长水平井钻探过程中的环空憋堵、井壁失稳技术难题，分析了该地层地质特征，并通过实验研究了其井壁失稳机理，研究表明川西海相地层最小主应力方向井壁失稳风险要高于最大主应力方向，储层岩石矿物呈现硬脆性，地层破碎，微裂缝发育，夹层胶结性差，长水平井段易发生岩屑沉积，引起环空憋堵，裂缝受压力激动进一步拓展，导致井壁失稳。在此基础上，研制了抗高温提切剂SMRS-1，研选了乳化剂和纳微米封堵剂SMNR-2等关键材料，构建了抗高温长效稳定白油基钻井液体系，该体系经160℃滚动老化7 d后，动塑比不小于0.20 Pa/mPa·s，高温高压滤失量（160℃）小于4.0 mL，破乳电压大于600 V，显示出良好的高温长效稳定性。该钻井液在PZ5-3井成功应用，解决了川西海相长水平井环空憋堵、井壁失稳难题。
- 川西气田 /
- 长水平井 /
- 井壁失稳 /
- 提切剂 /
- 油基钻井液
Abstract: In order to address the challenges of annular blockage and borehole instability during the drilling process of long horizontal wells in western Sichuan, this study analyzed the geological characteristics of the formation. Experimental research was conducted to understand the mechanism behind borehole instability. The findings revealed that in sea-related geological formations in Western Sichuan Basin, the risk of borehole instability is higher in the direction of minimum principal stress compared to that of maximum principal stress. The reservoir rock exhibits hard brittleness, fractured formations, developed microfractures, poor interlayer cementation, and a tendency for drilling cuttings deposition leading to annular blockage. Under pressure excitation, fractures further expand causing borehole instability. Based on these findings, flow type stabilizer SMRS-1 was developed. Emulsifying agents and nano-micron sealing agent SMNR-2 were carefully selected to construct a high-temperature long-term stable white oil-based drilling fluid system. After 7 days of rolling aging at 160℃, this system exhibited good high-temperature long-term stability with a dynamic viscosity ratio ≥0.20 and a high-temperature high-pressure filtration loss <4.0 mL at 160℃ along with breakdown voltage >600 V. The successful application of this drilling fluid in well PZ5-3 effectively resolved issues related to annular blockage and borehole instability encountered during long horizontal well drilling operations within western Sichuan.
- Western Sichuan gas field /
- Horizontal wells /
- Borehole instability /
- Flow type stabilizer /
- Oil-based drilling fluid

HTML全文

图 1 雷口坡组岩样扫描电镜

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图 2 雷口坡组白云岩三轴抗压强度随浸泡时间变化

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图 3 不同乳化剂在长时间老化后的乳化率变化

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图 4 SMRS-1红外光谱图

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图 5 在180℃下老化不同时间后钻井液的提切性能

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图 6 在180℃下老化不同时间后钻井液的沉降系数

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图 7 油水比80∶20白油基钻井液高温高压破乳电压变化

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图 8 油水比90∶10白油基钻井液高温高压破乳电压变化

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表 1 川西气田雷口坡组岩样及掉块矿物组分分析 %

样品号	石英	方解石	白云石
1	0.8	35.6	63.6
2	0.2	30.5	69.3
3	0.5	14.8	84.7
4	0	80.8	19.2
5	0	22.4	77.6
6	0.6	3.2	96.2
平均	0.35	31.2	68.5
注：黏度矿物含量为0。

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表 2 基浆中加入不同类型提切剂的提切性能

配方	PV/ mPa·s	YP/ Pa	YP/PV/ Pa/mPa·s	YP提高率/ %	动塑比提高率/%
空白	20	2.5	0.125
1%提切剂1	20	3.0	0.150	40	20.0
1%提切剂2	26	5.5	0.211	120	68.8
1%提切剂3	20	3.0	0.150	20	20.0
1%提切剂4	24	4.5	0.187	80	49.6
1%SMRS-1	25	6.5	0.260	160	108.0
注：老化条件180℃×16 h。

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表 3 封堵材料对钻井液性能影响

配方	AV/ mPa·s	PV/ mPa·s	YP/ Pa	YP/PV/ Pa/mPa·s	ES/ V	FL_HTHP/ mL
基浆	43.0	35	8.0	0.23	832	14.2
1^#	39.0	30	9.0	0.30	777	7.8
2^#	41.0	33	8.0	0.24	702	8.2
3^#	39.5	31	8.5	0.27	721	5.4
4^#	42.0	32	10.0	0.31	734	5.2
5^#	42.5	32	10.5	0.33	790	2.0

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表 4 钻井液长期老化性能

ρ/ g/cm³	老化条件	ES/ V	PV/ mPa·s	YP/ Pa	Gel/ Pa/Pa	YP/PV/ Pa/mPa·s	FL_HTHP/ mL
1.40	老化前	967	29	10.0	4.0/5.0	0.34
	160℃、1 d	1170	54	18.5	7.0/8.0	0.32	3.0
	160℃、3 d	804	50	16.0	7.0/8.0	0.23	3.0
	160℃、5 d	756	41	9.5	2.5/3.5	0.23	3.2
	160℃、7 d	653	35	8.0	2.0/3.0	0.22	3.4
1.50	老化前	1281	32	10.0	5.0/4.0	0.31
	160℃、1 d	1456	57	16.0	8.0/9.0	0.28	2.8
	160℃、3 d	936	45	12.0	2.5/3.5	0.27	3.4
	160℃、5 d	716	31	8.0	2.0/3.0	0.26	3.4
	160℃、7 d	653	28	6.0	2.0/3.0	0.21	3.6

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表 5 油基钻井液PPA封堵实验

配方	老化条件	50 μm砂盘		10 μm砂盘
配方	老化条件	瞬时滤失/ mL	V_PPA/ mL	瞬时滤失/ mL	V_PPA/ mL
基浆	160℃、1 d	56	110	22	60
油基钻井液	160℃、1 d	4.2	6.4	0	1.6
	160℃、3 d	5.8	7.0	1.8	2.4
	160℃、7 d	6.6	7.2	2.6	3.0

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表 6 现场钻井液在160℃老化不同时间后的性能

t_老化/ d	ES/ V	Gel/ Pa/Pa	AV/ mPa·s	PV/ mPa·s	YP/ Pa	YP/PV/ Pa/mPa·s	FL_HTHP/ mL	沉降系数
0	930	4.5/8.0	58.5	42	16.5	0.39	2.0	0.515
1	924	5.0/6.0	61.0	47	14.0	0.30	2.0	0.514
3	710	5.0/6.0	52.0	42	10.0	0.24	2.2	0.518
5	683	4.5/5.5	49.0	40	9.0	0.23	2.4	0.515
7	662	3.0/4.0.	46.0	38	8.0	0.21	2.6	0.520

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