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A Pressure-Drop Model for Oil-Gas Two-Phase Flow in Horizontal Pipes

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Fluid Dynamics & Materials Processing 2021年第2期17卷 371-383页

作者： Xinke Yang shanzhi shi Hui Zhang Yuzhe Yang Zilong Liu Ruiquan Liao Joseph X.F.Ribeiro Engineer Technology Research Institute of Xinjiang Oilfield Company Karamay834000China School of Petroleum Engineering Yangtze UniversityWuhan430100China Laboratory of Multiphase Pipe Flow of Gas Lift Innovation Center CNPC(Yangtze University)Wuhan430100China Kumasi Technical University KumasiGhana

The accurate prediction of the pressure distribution of highly viscous fluids in wellbores and pipelines is of great significance for heavy oil production and *** flow behavior of high-viscosity fluids is quite different with respect to that of low-viscosity ***,the performances of existing pressure-drop models seem to be relatively limited when they are applied to high-viscosity *** this study,a gas-liquid two-phase flow experiment has been carried out using a 60 mm ID horizontal pipe with air and white *** experimental results indicate that viscosity exerts a significant influence on the liquid holdup and pressure *** the same gas and liquid volume,both the liquid holdup and pressure drop increase with an increase in the *** two existing models,a modified pressure drop method is developed,which is applicable to horizontal pipes for different viscosities and does not depend on the flow *** new method displays a high accuracy in predicting the new experimental data presented here and other published data in literature.

关键词： Horizontal pipe different viscosities pressure drop model gas-liquid two-phase flow

Hydraulic fracture geometry and proppant distribution in thin interbedded shale oil reservoirs

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Petroleum Exploration and Development 2022年第5期49卷 1185-1194页

作者： ZOU Yushi shi shanzhi ZHANG shicheng LI Jianmin WANG Fei WANG Junchao ZHANG Xiaohuan State Key Laboratory of Petroleum Resources and Prospecting China University of PetroleumBeijing 102249China Engineering Technology Research Institute PetroChina Xinjiang Oilfield CompanyKaramay 834000China

Small-scale true triaxial sand fracturing experiments are conducted on thin interbedded shale samples made from cores of Permian Lucaogou Formation shale oil reservoir in Jimsar sag, Junggar Basin, NW China. Combined with high-precision CT scanning digital core model reconstruction technology, hydraulic fracture geometry and proppant distribution in thin interbedded shale oil reservoirs are studied. The research shows that: In thin interbedded shale oil reservoir, the interlayer difference of rock mechanics and the interlayer interface near the wellbore cannot restrain the growth of fracture height effectively, but has a significant impact on the fracture width distribution in the fracture height direction. Hydraulic fractures in these reservoirs tend to penetrate into the adjacent layer in “step-like” form, but have a smaller width at the interface deflection, which hinders the transport of proppant in vertical direction, resulting in a poor effect of layer-crossing growth. In shale layers with dense laminae, hydraulic fractures tend to form “丰” or “井” shapes. If the perforated interval is large in rock strength and high in breakdown pressure, the main fracture is fully developed initially, large in width, and supported by enough sand. In contrast, if the perforated interval is low in strength and rich in laminae, the fracturing fluid filtration loss is large, the breakdown pressure is low, the main fracture will not open wide initially, and likely to have sand plugging. Proppant is mainly concentrated in the main hydraulic fractures with large width near the perforated layer, activated laminae, branch fractures and fractures in adjacent layers contain only a small amount of(or zero) proppant. The proppant is placed in a limited range on the whole. The limit width of fracture that proppant can enter is about 2.7 times the proppant particle size.

关键词： shale oil thin interbedded reservoir rock mechanics lithologic interface hydraulic fracturing fracture shape proppant distribution

An analysis of the uniformity of multi-fracture initiation based on downhole video imaging technology: A case study of Mahu tight conglomerate in Junggar Basin, NW China

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Petroleum Exploration and Development 2022年第2期49卷 448-457页

作者： ZANG Chuanzhen JIANG Hanqiao shi shanzhi LI Jianmin ZOU Yushi ZHANG shicheng TIAN Gang YANG Peng State Key Laboratory of Petroleum Resources and Prospecting China University of PetroleumBeijing 102249China Engineering Technology Research Institute PetroChina Xinjiang Oilfield CompanyKaramay 834000China

To solve the problem that the production of Mahu conglomerate reservoir is not up to expectation after the multi-cluster plus temporary plugging fracturing technology is applied in horizontal wells, stages 2–6 in the test well MaHW6285 are selected to carry out erosion tests with different pumping parameters. The downhole video imaging technology is used to monitor the degree of perforations erosion, and then the fracture initiation and proppant distribution of each cluster are analyzed. The results showed that proppant entered 76.7% of the perforations. The proppant was mainly distributed in a few perforation clusters, and the amount of proppant entered in most of the clusters was limited. The proppant distribution in Stage 4 was relatively uniform, and the fracture initiation of each cluster in the stage is more uniform. The proppant distribution in stages 2, 3, 5, and 6 was significantly uneven, and the uniform degree of fracture initiation in each cluster is low. More than 70% of the proppant dose in the stage entered clusters near the heel end, so the addition of diverters did not promote the uniform initiation of hydraulic fractures. There was a positive correlation between the amount of proppant added and the degree of perforations erosion, and the degree of perforations erosion ranged from 15% to 352%, with an average value of 74.5%, which was far higher than the statistical results of shale reservoir tests in North America. The use of 180° phase perforation(horizontal direction) can reduce the “Phase Bias” of perforations erosion, promote uniform perforations erosion and fluid inflow. The research results provide the basis for optimizing the pumping procedure, reducing the perforation erosion and improving the success rate of diversion.

关键词： tight conglomerate temporary plugging fracturing perforation erosion fracture initiation downhole video imaging technology Junggar Basin Mahu sag

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考虑射孔孔眼磨蚀对多裂缝扩展的影响规律

天然气工业 2022年第10期42卷 63-73页

作者：张士诚杨鹏邹雨时石善志李建民田刚油气资源与探测国家重点实验室·中国石油大学(北京) 中国石油新疆油田公司工程技术研究院

我国非常规油气资源丰富,压裂技术是其开发的重要手段,其中极限限流压裂技术是促进水平井压裂段均匀改造的关键技术,但井下监测表明射孔孔眼动态磨蚀严重,制约了工艺应用效果。为了解决射孔孔眼动态磨蚀带来的多裂缝扩展形态不确定性影... 详细信息

我国非常规油气资源丰富,压裂技术是其开发的重要手段,其中极限限流压裂技术是促进水平井压裂段均匀改造的关键技术,但井下监测表明射孔孔眼动态磨蚀严重,制约了工艺应用效果。为了解决射孔孔眼动态磨蚀带来的多裂缝扩展形态不确定性影响,提高现场工艺实际应用效果,在水平井多裂缝竞争扩展模型基础之上耦合孔眼动态磨蚀模型,然后根据实际井下射孔成像数据校正数值模型,研究了孔眼磨蚀作用下多裂缝扩展行为以及限流射孔参数优化方法。研究结果表明:(1)孔眼磨蚀作用将显著增大孔眼直径和流量系数,迅速降低射孔摩阻,加剧各簇流量分配和多裂缝扩展的非均匀程度;(2)段内应力均匀分布时,孔眼磨蚀作用随着限流作用增强而增加;(3)段内应力非均匀分布时,高应力簇裂缝扩展容易受到抑制作用,考虑孔眼磨蚀作用后将进一步加剧各簇裂缝流量分配的非均衡程度,甚至导致高应力簇裂缝停止进液,裂缝不能充分扩展。结论认为,研究结果对孔眼动态磨蚀机理研究以及改进压裂工艺设计具有重要理论和现实意义,有助力我国非常规气油气的高效开发。

关键词：储层改造非常规油气多裂缝扩展孔眼动态磨蚀数值模拟限流压裂井下射孔成像

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玛湖油田致密砂砾岩储层岩心差应变实验

中国海上油气 2020年第3期32卷 86-93页

作者：何小东马俊修石善志刘刚谭强中国石油新疆油田分公司工程技术研究院新疆克拉玛依834000 北京阳光杰科科技股份有限公司北京100192 中国石油大学(北京)油气资源与探测国家重点实验室北京102249

为了获得新疆玛湖油田百口泉组致密砂砾岩储层地应力大小数据并指导压裂设计和施工,利用该储层段钻井中获取的砂砾岩和泥岩岩心进行了室内差应变实验,并依据实验数据对储层三向主应力大小进行了分析。实验结果表明,百口泉组储层段水平... 详细信息

为了获得新疆玛湖油田百口泉组致密砂砾岩储层地应力大小数据并指导压裂设计和施工,利用该储层段钻井中获取的砂砾岩和泥岩岩心进行了室内差应变实验,并依据实验数据对储层三向主应力大小进行了分析。实验结果表明,百口泉组储层段水平最大主应力与垂向主应力大小相近,砂砾岩储层水平最大主应力平均为71.8 MPa,水平最小主应力平均为51.1 MPa;泥岩隔层水平最大主应力平均为72.9 MPa,水平最小主应力平均为56.1 MPa。同时,利用压裂、成像测井等工程数据对水平最大、最小主应力进行评价,验证了差应变实验数据解释地应力大小的可靠性,表明通过差应变实验得出的主应力数值能够反映玛湖油田百口泉组致密砂砾岩储层现今地应力状态,可用于钻井、压裂等工程设计。

关键词：玛湖油田致密砂砾岩差应变实验地应力

基于钻头井底机械比能无监督聚类的水平井分段压裂段簇优化

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天然气工业 2023年第7期43卷 55-62页

作者：胡诗梦盛茂石善志李嘉成田守嶒李根生中国石油大学(北京)人工智能学院油气资源与探测国家重点实验室中国石油新疆油田公司玛湖勘探开发项目部中国石油新疆油田公司工程技术研究院

水平井多簇射孔分段压裂是非常规油气储层体积压裂改造主体技术之一,然而我国非常规储层普遍非均质性强,水平井段不同位置裂缝起裂压力差异较大,多簇射孔难以保证簇间裂缝的均衡起裂扩展,因此,亟须精细评价水平井段岩石强度的差异性,优... 详细信息

水平井多簇射孔分段压裂是非常规油气储层体积压裂改造主体技术之一,然而我国非常规储层普遍非均质性强,水平井段不同位置裂缝起裂压力差异较大,多簇射孔难以保证簇间裂缝的均衡起裂扩展,因此,亟须精细评价水平井段岩石强度的差异性,优选岩石强度相近井段布缝,以达到均衡改造的目的。为此,基于钻录井数据,建立了水平井段钻头井底机械比能无监督聚类模型,考虑了钻柱摩阻、复合钻进和射流辅助破岩等因素对井底机械比能的影响,获得了分米级空间分辨率的井底机械比能分布和聚类类别;最后综合考虑缝间应力干扰、套管接箍位置、桥塞位置和井底机械比能聚类结果,形成了以均衡改造为目标的水平井体积压裂布缝优化方法。研究结果表明:(1)相较脆性指数、泊松比、应力差等因素,射孔孔眼冲蚀面积与井底机械比能相关性较高,井底钻头机械比能可有效表征水平井段射孔簇进砂量的差异性,能够作为优选布缝位置的重要指标之一;(2)钻录井数据清洗与平滑、手肘法优选聚类数是获取井底机械比能聚类结果的关键步骤,可实现分米级分辨率区分井底机械比能的差异性;(3)优选了段内井底机械比能均值10%范围内布置射孔簇,所编制的计算机算法能自动优选压裂段簇位置,实现了段间距和簇间距的差异化设计。结论认为,该项研究成果可进一步提高非常规油气储层体积压裂布缝效率和压裂改造均衡性,该技术有望为非常规油气储层水平井体积压裂布缝优化提供思路和新方法。

关键词：非常规油气智能压裂水平井压裂压裂设计机械比能无监督聚类射孔簇参数优化

CO_2辅助蒸汽驱对四种钢的腐蚀性能影响模拟

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西南石油大学学报（自然科学版） 2018年第4期40卷 162-168页

作者：石善志董宝军曾德智于会永陈禹欣新疆油田工程技术研究院新疆克拉玛依8340002 "油气藏地质及开发工程"国家重点实验室.西南石油大学四川成都610500

CO_2辅助蒸汽驱是稠油开采的新型方式,但有关CO_2辅助蒸汽驱注气井中井下管柱CO_2腐蚀行为的研究较少。为此,利用高温高压釜模拟CO_2辅助蒸汽驱注气井筒工况,在CO_2分压为2MPa,240℃的条件下,对4种常用的油套管钢进行了失重腐蚀挂片试验... 详细信息

CO_2辅助蒸汽驱是稠油开采的新型方式,但有关CO_2辅助蒸汽驱注气井中井下管柱CO_2腐蚀行为的研究较少。为此,利用高温高压釜模拟CO_2辅助蒸汽驱注气井筒工况,在CO_2分压为2MPa,240℃的条件下,对4种常用的油套管钢进行了失重腐蚀挂片试验,得到了模拟工况下油套管钢的腐蚀速率,利用SEM观察了4种材质的微观腐蚀形貌,并采用SEM和EDS对4种管材的腐蚀产物进行了表征。结果表明,在实验条件下,4种材质的均匀腐蚀速率均小于油田的腐蚀控制指标(0.076 mm/a);N80钢的腐蚀形态为均匀腐蚀,而3Cr、9Cr和13Cr钢的腐蚀形态为局部腐蚀;4种钢材的腐蚀速率均满足CO_2辅助蒸汽驱注气井筒腐蚀控制要求。

关键词： CO2辅助蒸汽驱 CO2腐蚀井下管柱腐蚀速率腐蚀形貌

地质工程一体化在玛湖凹陷致密砂砾岩水平井开发中的实践

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中国石油勘探 2018年第2期23卷 90-103页

作者：刘涛石善志郑子君纪拥军王磊中国石油新疆油田公司能新科(西安)油气技术有限公司

准噶尔盆地玛湖凹陷东斜坡的玛东2井区致密砂砾岩储层埋藏深,物性差,水敏、压敏现象严重,储层岩体砾径分选性差,非均质性强,脆性差,导致其效益开发难度大。在吸取邻区经验的基础上,将地质认识和工程技术紧密结合,对玛东2井区内第一口评... 详细信息

准噶尔盆地玛湖凹陷东斜坡的玛东2井区致密砂砾岩储层埋藏深,物性差,水敏、压敏现象严重,储层岩体砾径分选性差,非均质性强,脆性差,导致其效益开发难度大。在吸取邻区经验的基础上,将地质认识和工程技术紧密结合,对玛东2井区内第一口评价水平井(玛东1号)的工程设计进行了大量研究论证,并引进先进技术保障实施效果。开展大量岩心实验和精细测井解释,摸清了区块砂砾岩的岩性和物性;采用精细地震采集、解释和建立砂砾岩储层分类方法,优选了目的层和轨迹;采用先进地质导向工具并利用模型重构技术实时调整,确保了钻遇率和钻井效率;通过试油分析和数值模拟分析影响砂砾岩储层压裂增产的因素,进行了工艺技术优化等。通过多学科的协调配合,玛东1号水平井在含水稳定后,采用3mm油嘴生产时的平均产油量达到53.9t/d,取得了远超区块直井的提产增效成果。

关键词：地质工程一体化玛湖凹陷致密油砂砾岩储层改造

致密砾岩加砂压裂与裂缝导流能力实验--以准噶尔盆地玛湖致密砾岩为例

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石油勘探与开发 2021年第6期48卷 1202-1209页

作者：邹雨时石善志张士诚俞天喜田刚马新仿张兆鹏中国石油大学(北京)油气资源与探测国家重点实验室北京102249 新疆油田公司工程技术研究院新疆克拉玛依834000

选取准噶尔盆地玛湖凹陷二叠系乌尔禾组砾岩岩心开展真三轴加砂压裂实验,研究杂基支撑细砾岩、颗粒支撑中砾岩水力裂缝扩展形态与石英砂支撑剂运移情况,并通过3D打印技术对砾岩压后粗糙面进行重构,分析粗糙面对导流能力的影响。研究表明... 详细信息

选取准噶尔盆地玛湖凹陷二叠系乌尔禾组砾岩岩心开展真三轴加砂压裂实验,研究杂基支撑细砾岩、颗粒支撑中砾岩水力裂缝扩展形态与石英砂支撑剂运移情况,并通过3D打印技术对砾岩压后粗糙面进行重构,分析粗糙面对导流能力的影响。研究表明:杂基支撑细砾岩水力裂缝整体相对平直,仅局部遇较大砾石时迂曲明显,易于加砂,缝内支撑剂运移距离约占缝长的70%~90%;颗粒支撑中砾岩水力裂缝以绕砾扩展为主,路径迂曲,缝宽多变,不易加砂,缝内支撑剂运移距离不足缝长的30%。杂基支撑细砾岩因基质含量高且硬度较低,缝内支撑剂嵌入缝面较为严重;而颗粒支撑中砾岩砾石含量高,硬度较大,缝内支撑剂破碎严重;高铺砂浓度(5 kg/m^(2))条件下,提高闭合应力(大于60 MPa),杂基支撑细砾岩、颗粒支撑中砾岩压后缝宽均大幅减小,导流能力较20 MPa低闭合应力时分别下降88%和92%。现场试验证实,在60 MPa以上高闭合应力下,保证高铺砂浓度的同时,使用高比例小粒径支撑剂,有利于增大运移距离,且支撑剂在粗糙缝内相对均匀铺置,裂缝导流能力较高,油井产量高且稳定。

关键词：杂基支撑细砾岩颗粒支撑中砾岩加砂压裂裂缝扩展支撑剂运移裂缝导流能力

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