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满深区块深井强封堵钻井液技术

喻化民,  薛莉,  吴红玲,  李海彪,  冯丹,  杨冀平,  鲁娜

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文章导航 > 钻井液与完井液  > 2022 >  39(2): 171-179
喻化民，薛莉，吴红玲，等. 满深区块深井强封堵钻井液技术[J]. 钻井液与完井液，2022，39（2）：171-179 doi: 10.12358/j.issn.1001-5620.2022.02.007
引用本文: 喻化民，薛莉，吴红玲，等. 满深区块深井强封堵钻井液技术[J]. 钻井液与完井液，2022，39（2）：171-179 doi: 10.12358/j.issn.1001-5620.2022.02.007
shu
YU Huamin, XUE Li, WU Hongling, et al.Drilling fluid with superior plugging performance used in deep well drilling in manshen block[J]. Drilling Fluid & Completion Fluid，2022, 39（2）：171-179 doi: 10.12358/j.issn.1001-5620.2022.02.007
Citation: YU Huamin, XUE Li, WU Hongling, et al.Drilling fluid with superior plugging performance used in deep well drilling in manshen block[J]. Drilling Fluid & Completion Fluid，2022, 39（2）：171-179 doi: 10.12358/j.issn.1001-5620.2022.02.007
shu

满深区块深井强封堵钻井液技术

doi: 10.12358/j.issn.1001-5620.2022.02.007
  • 1.

    中国石油集团渤海钻探工程技术研究院, 河北任丘 062550

  • 2.

    中国石油集团华北油田分公司第三采油厂, 河北河间062450

基金项目: 中石油渤海钻探工程技术研究院科技项目“塔河地区深井强封堵钻井液技术研究与应用”（2021Y21K）
详细信息
    作者简介:

    喻化民，高级工程师，1981年生，2005年毕业于长江大学应用化学专业，现在从事钻井液技术研究与应用工作。E-mail：93331573@qq.com

  • 中图分类号: TE254.4

Drilling Fluid with Superior Plugging Performance Used in Deep Well Drilling in Manshen Block

  • 1.

    Engineering Technology Research Institute, CNPC Bohai Drilling Engineering Company Limited, Renqiu, Hebei 062550

  • 2.

    The Third Oil Production Plant, PetroChina Huabei Oilfield Company, Hejian , Hebei 062450

    摘要
  • 摘要: 满深区块中深部地层断裂破碎，微裂缝发育，且黏土矿物含量高，组分差异大，硬脆性和水敏性泥页岩相互共存，钻井过程中易发生水力劈裂和水化不等速膨胀而导致的井壁失稳。为此，提出了“物理支撑+化学抑制封堵”防塌技术对策，并构建了多元协同防塌强封堵钻井液。室内评价表明：强封堵钻井液抗温达180 ℃；抗10%饱和盐水污染；T层和S层岩样滚动回收率高达89.36%和91.33%、膨胀率低至7.3%和4.2%；能有效封堵20～120目不同粒径石英砂间微孔隙。该钻井液在ManS5-H4井现场应用中性能稳定，流变性好，滤失量低，具有较好的抑制和防塌性能，解决了中深部地层阻卡、坍塌掉块和扩径等井壁失稳问题，井眼通畅规则，二、三开井段平均井径扩大率分别为4.28%和6.75%，返出岩屑代表性好，无钻井液事故发生，能满足复杂地层复杂工艺钻进需要，提高了钻井综合效益。

     

    Abstract: The deep formations drilled in the Manshen block are broken and full of microfractures. They have high clay contents with large differences in clay composition. Hard and brittle shales and water-sensitive shales are coexisting in the formations drilled. These formations easily lose their stability during drilling because of hydraulic splitting and difference in the speed of hydration. A technical measure named “physical support plus chemical inhibition and plugging” was presented and an anti-collapse drilling fluid with superior plugging capacity formulated to deal with the borehole wall instability problem. Laboratory study showed that the drilling fluid functioned normally at 180 ℃ and was able to resist contamination by 10% saltwater. Shale samples taken from the T layer and S layer were tested in the drilling fluid formulated. Hot rolling test gave percent cuttings recovery of 89.36% and 91.33% respectively, and expansion test gave rate of expansion of 7.3% and 4.2% respectively. This drilling fluid can plug the pores in cores made with quartz particles from 20 mesh to 120 mesh. In drilling the well ManS5-H4, the drilling fluid showed stable properties and had low filtration rate. It had good inhibitive capacity and collapse prevention performance. Tripping was smooth with no overpulls and resistance, the second and the third interval found average hole enlargement of 4.28% and 6.75% respectively. The cuttings returned to the shake shakers kept their original shakes and no downhole troubles were ever encountered. This drilling fluid has satisfied the needs of drilling the complex formations and saved the total cost of drilling.

     

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  • 图  1  强封堵钻井液抑制性评价实验结果对比图

    下载: 全尺寸图片 幻灯片

    图  2  ManS5-H4实钻钻井液性能

    下载: 全尺寸图片 幻灯片

    图  3  ManS5-H4井井径扩大率

    下载: 全尺寸图片 幻灯片

    表  1  满深区块各层段黏土矿物组分平均相对含量

    层
    位    		样品数
    （个）    		黏土矿物组份相对含量/%混层比/%
    IKCI/SC/SI/S混层C/S混层
    J815.6065.9011.407.10　25　
    T77.806.307.3078.60　75～100　
    P上413.8013.0014.0059.20　65～85　
    P下513.607.806.2061.401150～65　
    C上638.805.709.7045.80　50～80　
    C下516.6054.408.8020.20　15～25　
    D上1922.167.268.4262.16　20～70　
    D下818.257.6253.7520.38　15～30　
    S上1240.756.5815.2537.42　20　
    S中627.6710.5014.3020.2027.332020～30
    S下1420.282.5745.7131.44　20　
    O2344.489.2622.5223.74　20　
    下载: 导出CSV

    表  2  KCl加量对钻井液性能的影响

    KCl/
    %    		实验条件回收率/
    %    		ρ/
    g·cm−3    		PV/
    mPa∙s    		YP/
    Pa    		Gel/
    Pa/Pa    		FLAPI/
    mL
    0常温80.601.302018.56.0/9.56.8
    80 ℃×16 h1.302221.06.5/11.56.0
    1常温87.601.321519.05.5/6.58.0
    80 ℃×16 h1.321821.05.5/6.56.8
    3常温89.061.321517.04.5/5.58.3
    80 ℃×16 h1.321817.54.5/5.57.4
    5常温94.061.321517.04.0/5.08.6
    80 ℃×16 h1.321717.53.5/4.57.8
    7常温95.801.321516.03.5/5.09.0
    80 ℃×16 h1.321717.03.0/4.58.2
    10常温93.841.321516.03.5/4.510.4
    80 ℃×16 h1.321816.03.0/4.59.6
    　注：配方：3%膨润土+0.3%Na2CO3+0.1%NaOH+0.6%
    IND30+0.5%NH4-HPAN-2+0.5%THJN+加重剂；pH值为9
    下载: 导出CSV

    表  3  在基浆中加入不同防塌剂的性能（150 ℃、16 h）

    防塌剂PV/
    mPa·s    		YP/
    Pa    		Gel/
    Pa/Pa    		FLAPI/
    mL    		FLHTHP/mL
    120 ℃150 ℃
    051.51.0/3.012.020.025.0
    2%SY-A0163.02.0/4.07.014.818.5
    2%FT34281.50.5/1.57.816.421.0
    3% DYFT-285.01.5/5.04.413.617.0
    2%FT10361.00.5/2.57.617.626.0
    3%FT-160.50.5/2.08.918.019.2
    3%FT-1A103.51.5/3.54.814.217.6
    3%RLQ-282.00.5/3.07.215.519.0
    2%YX52.01.5/4.010.816.824.2
    　注：基浆为：5%膨润土浆+5%SMP-3+5%SPNH+7%KCl+
    0.2%NaOH
    下载: 导出CSV

    表  4  封堵防塌剂优选复配性能评价实验（150 ℃、16 h）

    防塌剂PV/mPa·sYP/PaGel/(Pa/Pa)FLAPI/mLFLHTHP/mL
    051.51.0/3.012.025.0
    2%DYFT-2+2%FT-1A92.52.5/5.06.817.2
    2%DYFT-2+2%FT-1A +2%SYA01102.52.5/6.55.515.6
    2%DYFT-2+2%FT-1A +2%YX94.52.5/6.54.014.8
    2%DYFT-2+2%FT-1A+2%YX+2%SQD-98(细)125.03.0/8.03.213.2
    2%DYFT-2+2%FT-1A+2%YX+2%DF-195.03.0/7.03.614.2
    　注：FLHTHP在150 ℃测定
    下载: 导出CSV

    表  5  降滤失剂优选性能评价实验（150 ℃、16 h）

    降滤失剂PV/mPa·sYP/PaGel/(Pa/Pa)FLAPI/mLFLHTHP/mL
    094.02.0/6.04.515.2
    0.3%CMC-LV156.01.5/7.02.814.6
    0.5%XCD-LV153.54.5/7.512.422.0
    0.3%PAC-LV217.01.5/9.02.213.8
    0.5%Redul185.01.0/8.52.314.0
    0.3%PAC-LV+0.5%Redul3116.02.0/11.01.88.6
    0.3%PAC-LV+2%KJAN2212.02.5/10.03.010.4
    0.3%PAC-LV+0.5%NH4-HPAN-2268.51.5/10.52.812.4
    0.3%PAC-LV+2%JNF-3185.01.5/8.52.09.2
    0.3%PAC-LV+2%TYJS-1165.01.5/6.52.49.8
    　注：基浆配方：5%膨润土浆+0.4%NaOH +3%SMP-3+3%SPNH +7%KCl +2% DYFT-2 +2%FT-1A +2%YX+2%润滑剂；钻井液密度为1.36 g/cm3；FLHTHP在150 ℃测定
    下载: 导出CSV

    表  6  强封堵钻井液抗温性能评价实验

    测试
    条件    		PV/
    mPa·s    		YP/
    Pa    		Gel/
    Pa/Pa    		FLAPI/
    mL    		FLHTHP/
    mL    		pH
    老化前206.02.5/11.03.29
    150 ℃、16 h185.03.0/9.02.89.69
    150 ℃、24 h185.02.5/9.02.89.89
    150 ℃、48 h174.02.0/7.03.010.69
    180 ℃、16 h162.51.5/5.54.514.29
    　注：钻井液密度为1.36 g/cm3；FLHTHP在150 ℃测定
    下载: 导出CSV

    表  7  强封堵钻井液钻井液砂床封堵性评价实验

    砂床粒径/目砂床高度/cmP/MPat/min侵入深度/cm
    20～40 30 0.7 480 4.9
    40～80 30 0.7 480 4.2
    80～100 30 0.7 480 3.4
    100～120 30 0.7 480 2.6
    下载: 导出CSV

    表  8  在强封堵钻井液中加入饱和盐水的抗盐水污染性能

    饱和盐水/
    %    		ρ/
    g·cm−3    		PV/
    mPa·s    		YP/
    Pa    		Gel/
    Pa/Pa    		FLAPI/
    mL    		FLHTHP/
    mL    		pH
    01.36185.03.0/9.02.89.59.0
    51.35175.03.0/8.03.011.89.0
    101.33143.52.0/5.53.814.68.5
    151.28123.01.0/3.05.219.88.0
    201.25111.00.5/1.05.822.48.0
    下载: 导出CSV
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  • 收稿日期:  2021-10-26
  • 修回日期:  2021-11-21
  • 录用日期:  2021-10-21
  • 刊出日期:  2022-06-23

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