河探1井超高密度钻井液技术

王信; 谭春; 王志彬; 罗玉财; 周燚; 张民立; 王威; 贾东民

doi:10.12358/j.issn.1001-5620.2023.02.007

河探1井超高密度钻井液技术

doi: 10.12358/j.issn.1001-5620.2023.02.007

王信^1,,
谭春²,
王志彬¹,
罗玉财³,
周燚¹,
张民立¹,
王威⁴,
贾东民⁵

1.
中国石油集团渤海钻探泥浆技术服务分公司, 天津300280
2.
中国石油集团渤海钻探巴彦石油工程分公司, 内蒙古巴彦淖尔 015000
3.
中国石油华北油田勘探部, 河北任丘 062552
4.
中国石油集团渤海钻探定向井分公司, 天津300280
5.
中国石油集团渤海钻探工程技术研究院, 河北任丘 062550

详细信息

作者简介:
王信，中油集团公司钻井液技能专家，一直从事钻井液、完井液技术研究及现场应用工作。电话 18702245139; E-mail：495113347@qq.com

中图分类号: TE254.3
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出版历程
- 收稿日期: 2022-11-28
- 修回日期: 2022-12-30
- 刊出日期: 2023-03-30

Ultra-High Density Drilling Fluid Technology for the Well Hetan-1

1.
Drilling Fluid Technology Services of CNPC Bohai Drilling Engineering Company Limited, Tianjin 300280
2.
Bayan Petroleum Engineering Branch of CNPC Bohai Drilling Engineering Company Limited, Bayannur, Inner Mongolia 015000
3.
Exploration Department of CNPC Huabei Oilfield, Renqiu, Hebei 062552
4.
Drilling directional Well Technology Services of CNPC Bohai Drilling Engineering Company Limited, Tianjin 300280
5.
Engineering Technology Research Institute of CNPC Bohai Drilling Engineering Company Limited, Renqiu, Hebei 062550

摘要

摘要: 河探1井是中油股份公司在华北油田河套盆地临河坳陷部署的一口重点风险探井，完钻井深为6460.44 m，钻探目的为探索兴隆构造带光明背斜古近系、新近系生储盖特征及其含油气性。该井三开钻遇四套不同压力系数复杂地层，钻井液密度窗口窄，现场顺利实施了提密度压井、堵漏，控压钻进等作业，四开钻遇异常高压流体层，应用超高密度钻井液体系一次性将钻井液密度从1.80 g/cm³提高至2.55 g/cm³，并安全实施完井作业，储备压井高密度钻井液（ρ=2.60 g/cm³），达到国内应用水基钻井液采用重晶石粉加重的极限。在钻井施工过程中先后出现井塌、膏泥岩层蠕变缩径卡钻、高压盐水侵以及井漏等事故复杂，采用超高密度抗高温复合盐钻井液，现场应用随钻封堵提高地层承压能力工艺，分段完成七次承压堵漏，同时强化一级固控有效使用，应用高目筛布、优化钻井液体系配方、优选加重材料、调节膨润土含量及合理控制低密度固相含量等手段，成功解决了窄密度窗口和超高密度水基钻井液高温、高固相流变性能调整困难等技术难题，确保了压井和试油作业期间高温条件下超高密度钻井液体系具有良好的稳定性。该井创地区同期六项钻井技术指标，日产302.4 m³高产工业油流，实现巴彦油田最深井勘探发现，为钻井及完井试油作业提供了技术支撑。
- 河套盆地 /
- 超高密度水基钻井液 /
- 窄窗口 /
- 加重材料 /
- 固相含量 /
- 沉降稳定性
Abstract: The well Hetan-1 is a key exploratory well drilled by CNPC at the Linhe depression in the Hetao basin in Huabei oilfield. The completion depth of this well is 6,460.44 m and was drilled to explore the reservoir characteristics of the Paleogene and the Neogene systems in the Guangming anticline in the Xinglong tectonic belt. The third interval of this well penetrated formations of four different formation pressure coefficients, and the safe drilling windows of the formations are narrow. Killing the well by raising mud weight, controlling mud losses and drilling with managed pressure were used in drilling this interval. When drilling into the formation with ultra-high pressure fluids, the mud density was increased in one step from 1.80 g/cm³ to 2.55 g/cm³, and the well was successfully completed. The kill mud stored at the rig site had a density of 2.60 g/cm³, a density limit of water based drilling fluids weighted with barite. Several downhole troubles were encountered during drilling, such as borehole collapse, pipe sticking because of creeping tight hole in mudstone formations containing gypsum, high pressure saltwater invasion as well as mud losses. The interval was drilled with a high temperature ultra-high density compound saltwater drilling fluid, and controlling mud losses while drilling technique was used seven times to enhance the pressure bearing capacity of the formations. During drilling, finer screens were used on shale shakers for better solids control, the drilling fluid was continually optimized for its composition, the weighting materials were carefully selected, the content of bentonite in the mud was adjusted to satisfy the needs of stabilizing mud rheology, and the content of the low-gravity solids in the mud was carefully controlled at as low as possible level. With these measures, problems such as narrow drilling windows, difficulties in controlling the rheology of a high temperature high solids content drilling fluid with ultra-high density were successfully solved, ensuring the stability of the properties of the ultra-high density drilling fluid in high temperature drilling and completion operations. The drilling of this well has created six drilling technical indicators in this area at the same period. An industrial oil flow of 302.4 m³ was produced daily, realizing the target of exploring oil and gas in the deepest well in the Bayan oilfield, and of providing technical support to the drilling and completion operations.
- Hetao basin /
- Ultra-high density water based drilling fluid /
- Narrow drilling window /
- Weighting material /
- Solids content /
- Settling stability

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图 1 河探1井三开钻屑电镜扫描照片

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表 1 不同降滤失剂单剂的抗高温性能

基浆配方	实验条件	AV/ mPa·s	PV/ mPa·s	YP/ Pa	FL_API/ mL	FL_HTHP/ mL
3.5%膨润土浆+0.1%烧碱+2%Redu2	常温	54.0	45	9.0	12.0
3.5%膨润土浆+0.1%烧碱+2%Redu2	200 ℃、16 h	13.0	12	1.0	22.0	48
3.5%膨润土浆+0.1%烧碱+2%Redu2+50%有机盐	常温	38.0	30	8.0	12.5
3.5%膨润土浆+0.1%烧碱+2%Redu2+50%有机盐	200 ℃、16 h	28.0	22	6.0	17.5	28
3.5%膨润土浆+0.1%烧碱+2%Redu200	常温	38.0	33	5.0	7.2
3.5%膨润土浆+0.1%烧碱+2%Redu200	200 ℃、16 h	24.5	24	0.5	7.0	24
3.5%膨润土浆+0.1%烧碱+2%Redu200	常温	38.0	33	5.0	7.2
3.5%膨润土浆+0.1%烧碱+2%Redu200	220 ℃、16 h	23.0	20	3.0	15.0	45
3.5%膨润土浆+0.1%烧碱+2%Redu200+50%复合有机盐	常温	30.0	23	7.0	8.5
3.5%膨润土浆+0.1%烧碱+2%Redu200+50%复合有机盐	220 ℃、16 h	20.0	15	5.0	11.0	29

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表 2 在基浆中加入不同加量纳米封堵剂NAX50的性能

NAX50/ %	φ₆₀₀/ φ₃₀₀	AV/ mPa·s	PV/ mPa·s	YP/ Pa	FL_API/ mL	滤失量降低率/%
0	4/3	2.0	1	1.0	43.0
1	6/4	3.0	2	1.0	18.0	58.1
2	7/5	3.5	2	1.5	16.8	60.9
3	10/6	5.0	4	1.0	10.4	75.8
4	11/6	5.5	5	0.5	8.6	80.0
5	12/7	6.0	5	1.0	7.4	82.8
注：基浆为：350 mL水+1.05 g无水Na₂CO₃+28 g钻井液试验用评价土

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表 3 纳米封堵剂NAX50的封堵性能

实验配方	不同时间的滤失量/mL
实验配方	1 min	2 min	7.5 min	30 min
水	198.0	244.0	全滤失
5%NAX50溶液+0.15% 十二烷基硫酸钠	8.0	9.8	12.0	19.2
5%NAX50溶液	7.6	9.0	10.8	17.2

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表 4 不同有机盐钻井液的抗温性

钻井液	实验条件	ρ/ g·cm⁻³	φ₆/ φ₃	Gel/ Pa/Pa	AV/ mPa·s	PV/ mPa·s	YP/ Pa	FL_API/ mL	FL_HTHP/ mL
1^#	热滚前	1.35	3/2	1.0/3.0	42.0	34	8.0	0.8
1^#	热滚后	1.34	3/2	1.0/2.0	48.5	44	4.5	1.0	8.4
2^#	热滚前	1.85	4/3	1.5/6.0	82.5	68	14.5	1.2
2^#	热滚后	1.84	4/3	1.0/3.0	68.5	58	10.5	2.0	11.2
3^#	热滚前	2.50	7/5	3.0/12.5	121.0	109	12.0	1.2
3^#	热滚后	2.49	4/3	2.0/5.0	104.5	99	5.5	0.8	8.8
注：热滚条件为220 ℃、16 h，60 ℃测试流变性，常温下测试FL_API和密度。1^#、2^#配方无沉降，3^#配方软沉3～4 cm，钻井液密度加重至2.00 g/cm³以后，选用高密度重晶石粉

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表 5 复合有机盐钻井液抗盐及抗岩粉污染实验

污染物	实验条件	ρ/ g·cm⁻³	Gel/ Pa/Pa	PV/ mPa·s	YP/ Pa	FL_API/ mL	FL_HTHP/ mL
0	常温	2.50	1.5/6.0	38	8.5	1.4	11.2
20%NaCl	热滚后	2.50	1.5/4.5	41	8.0	1.6	11.6
0	常温	2.50	1.5/6.0	38	8.5	1.4	11.2
5%CaCl₂	热滚后	2.50	2.0/5.0	39	6.5	1.4	11.4
0	常温	1.48	1.5/4.5	37	8.5	1.4	11.2
5%岩粉	常温	1.50	1.5/4.5	38	8.5	1.2	11.2
10%岩粉	常温	1.52	2.0/5.0	39	7.0	1.2	11.0
注：热滚条件为180 ℃、16 h, FL_HTHP在180 ℃测试，60 ℃检测流变性能，常温下测试FL_API和密度

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表 6 河探1井四开及完井期间钻井液的流变性能

ρ/ g·cm^-3	FV/ s	φ₆₀₀/ φ₃₀₀	φ₂₀₀/ φ₁₀₀	φ₆/ φ₃	Gel/ Pa/Pa	AV/ mPa·s	PV/ mPa·s	YP/ Pa
1.86	80	120/71	40/21	2.0/1.0	0.5/2.5	60	49	11.0
1.95	107	156/90	55/29	3.0/1.5	1.5/3.5	78	66	12.0
2.26	94	196/113	57/31	3.0/2.0	1.5/3.0	98	83	15.0
2.45	110	260/139	97/53	6.0/3.0	2.5/7.5	130	121	9.5
2.55	130	226/124	87/48	6.0/3.0	4.5/11.0	113	102	11.0

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