地层漏失钻井处理技术在沙特KHURAIS地区的应用

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沙尔湖煤田第四系地层漏失堵漏的应用实践

遇到砂砾石层，此地层疏松多孔，弱的泥质胶结一无胶结，含有裂隙，胶结物遇水溶蚀，施工中常有漏失严重的现象。在遇到黄土层时，泥浆会溶蚀裂隙地层，加大
在钻探施工中泥浆起着关键作用，是保护孔壁稳定，预防渗漏的主要手段。在砂岩、砾石层轻微漏失地
百米不等。钻探施工中漏失层位多、裂隙大，遇到砂土、砾石层孔隙率大、裂隙多，易造成严重漏失，故在施工中是常要解决的问题。
关键词：砂砾石层；钻孔漏失；泥浆溶蚀；堵漏
中图分类号：ＴＥ２４９文献标识码：Ｂ文章编号：１００４ — ５７１６（２０１４）０４ — ００３３ — ０３１矿区工程地质条件矿区第四系地层分布于本区中北部的地表一浅表层处。上部为松散胶结的砾石、砂、黄土层；下部为一
西部探矿工程
２０１４年第４期
Ｎａ－ＣＭＣ要提前按配方浓度侵泡成溶液。泥浆主要性能为失水量８ｍＩ／３０ｍｉｎ，泥饼厚度０．８ｍｍ，粘度２３ｓ，比重在０．９８，ｐＨ值ｌ３。４．１．２泥浆材料的选用及作用
３．１渗透性漏失
４．１．１渗透性漏失地层泥浆配制及性能沙尔湖矿区渗透性漏失层主要出现在砂岩、砾石层，矿区泥浆配置方法是７００￣８００ｋｇ清水中加入纯碱４ｋｇ，膨润土４０￣５０ｋｇ，腐植酸钾４０￣５０ｋｇ，聚丙稀酸钾

地质钻探堵漏新技术的应用岳盈括

地质钻探堵漏新技术的应用岳盈括发布时间：2021-11-03T07:17:38.812Z 来源：《建筑学研究前沿》2021年16期作者：岳盈括[导读] 地质钻探是一项重要的工作。

此项工作的复杂性高、专业性强，因而在地质钻探工作中，地层漏失的出现频次相对较高。

这一问题如若得不到及时有效的处理，将会打乱钻井液的循环作业，孔内压力的平衡状态被打破，所引起的钻井事故更会引起严重的人员伤亡和经济损失。

山东省地质矿产勘查开发局第五地质大队山东省泰安市 271000摘要：地质钻探是一项重要的工作。

此项工作的复杂性高、专业性强，因而在地质钻探工作中，地层漏失的出现频次相对较高。

现阶段，随着地质钻探方面的技术越发成熟，市场上出现了越来越多的堵漏新技术。

这些新技术的出现，对预防地层漏失现象有着重要的作用，未来有着巨大的发展潜力。

关键词：地质钻探；堵漏；新技术；应用1钻孔漏失问题产生的原因 1.1客观原因地质钻探工作中的钻孔漏失问题较为常见，这一问题所引起的地质钻探问题非常突出。

相关研究表明，引发钻孔漏失现象的原因非常多，但总体上包含了客观因素和主观因素。

从客观性角度出发，钻孔漏失问题在很大程度上是地质钻探现场的地质水文条件所引起的，再进一步细分，岩层内孔隙环境、溶隙性环境、裂隙环境或者上覆岩层含水等，都会在一定程度上引发钻孔漏失问题。

因此，在地质钻探工作推进的过程中，为了提升工作成效，应在前期的工作中全面做好调查，详细了解地质钻探现场的地质水文条件，制订切实可行的地质钻探方案。

比如，以某煤田为研究对象，此煤田现场属于奥陶统峰峰组，地层厚度在245m左右，包含了石灰岩、白云质灰岩、局部泥质灰岩、石膏层；下二叠统山西组地层厚度约为70m，其中，分布有泥质岩、石灰岩、砂岩与煤层；中二同上石盒子组厚度达520m，包含砂岩、泥岩与砂质岩，在地质钻孔作业中，岩石孔隙和裂隙发育明显，加剧了钻井液漏失。

沙特高温高压钻井难点与技术应用研究

司在海外的重点探区之一。沙特区块具有高温高压、漏失、含硫化氢及多套压力体系共存的复杂地
质情况，深入分析该区块复杂地质情况，相应地制定合理井身结构、选用配套钻井工艺技术，配套固井技术，提高该地区钻井速度与效率、低钻井作业成本，提高勘探开发效率。沙特区块的勘探难点与技术应用研究对其他项目有极其重要的借鉴意义。
高温高压增加井控风险。在下部地层钻井过程中，
将钻遇多个高压气层，井底温度超过１６０￣（２，井底压力超过７０ＭＰａＵｎ — ａｙｚａｈ地层和Ｓａｒａｈ等高压地层易发生气侵、井涌，对井
钻井液性能的维护处理较为困难，若维护处理不当，易造成井下复杂、损害储层并增大钻井液的成本费用。高温高压增加井下工具选择难度。高温高压对入井的井下工具仪器也是一项严峻考验，特别是像井下马达、尾管悬挂器、ＭＷＤ等这类专用工具仪器，给钻井
西部探矿工程
２０１４年第４期
沙特高温高压钻井难点与技术应用研究
王学杰
伸石化集团国际石油勘探开发有限公司，北京１０００２９）摘要：沙特Ｂ区块是中石化国际勘探公司与沙特阿美公司合作的一个勘探区块，也是国际勘探公
度大、钻井周期长。已完钻井的井深接近６０００ｍ，井眼

新的滑行钻进技术在沙特阿拉伯的水平井钻井中成功应用

新的滑⾏钻进技术在沙特阿拉伯的⽔平井钻井中成功应⽤ABSTRACTWith the focus on continuous drilling optimization, a collaborative effort was implemented to analyze and assess drilling challenges encountered while drilling extended horizontal wells in the Khurais field in Saudi Arabia. The primary goal was to enhance the efficiency of conventional downhole motor systems for directional drilling in the challenging horizontal reservoir section.Khurais field is located in a remote area in the central part of Saudi Arabia, approximately 200 km from the Saudi capital, Riyadh, and 300 km from the Eastern Province port city of Dammam. The producer wells are drilled in the middle of the field and the water injector wells are drilled close to the field boundaries.An average of 12 rigs worked simultaneously throughout the duration of the project to drill and complete the required increment wells. The horizontal wells comprise the producers, trilateral producers and power water injectors. The wells are drilled to an average measured depth (MD) of 14,000 ft, with an average of 6,500 ft of open hole section across the reservoir. The 6?” horizontal open hole section is particularly challenging. It is drilled with steerable mud motors with the assistance of real time geosteering and logging while drilling tools to maintain the horizontal open hole section of the well close to the top of the reservoir within a window of 3 ft.The fracture intervals, coupled with high permeability, make the drilling of this section particularly challenging, as mud losses are frequently encountered in this section. The main difficulties to surmount to improve the efficiency of the directional drilling process are high drag and differential sticking.To overcome these challenges, the drilling team utilized a new sliding technology that interacts with the drilling rig top drive to break the static friction, improving the weight transfer to the bit and thereby increasing the rate of penetration (ROP). Through its virtual elimination of differential sticking and its reduction of buckling problems, this system helps to deliver weight smoothly down to the bit. Additional benefits of this innovative technology are the prevention of mud motor stalling, a steady orientation of the tool face and easier steering.This article describes the innovative system utilized to improve the ROP during the sliding process by almost 50% and presents real cases supported by field data. It also underscores the importance of post-action reviews and rig crew training in the achievement of record ROP in the sliding mode. Historical cases are presented, and the benefits of the application of this technology in these wells are explained.INTRODUCTIONAn innovative slider system was trial tested in the 6?”horizontal section of Khurais’ power water injector wells across the reservoir. This section was drilled through the Arab formation, consisting of four members composed of porous layers of carbonates separated by anhydrite. Because special equipment was to be run across the open hole section, it was very important to drill a smooth well path with minimum tortuosity and to avoid abrupt changes in well direction (high doglegs). The equipment that subsequently was run in this well consisted of an open hole completion with up to six open hole packers and 35 inflow control devices to isolate fractures and improve injection distribution. In addition, acid stimu-lation jobs were conducted with coiled tubing were usually done across this interval. Figure 1 shows a schematic of a typical power water injector well.This section was drilled with roller cone bits and steerable motors with an outer diameter of 5” and a rotor stator lobe ratio of 6/7 — this configuration represents a low revolution, high torque motor. The motor included a bend at the motorbearing housing at approximately 7 ft from the bit. TheFig. 1. Design of a typical power water injector well.Successful Application of New Sliding Technology for Horizontal Drilling inSaudi ArabiaAuthors: Roberto H. Tello Kragjcek, Abdullah S. Al-Dossary, Waleed G. Kotb and Abdelsattar H. El-Gamaldistance from the bent housing of the motor to the bit determines the maximum angle change that can be reached. The typical adjustable bent housing angle utilized was 1.5°. In some cases, the required dogleg rate in the horizontal section could reach up to 6°/100 ft; this occurred when adjustmentsin the well profile were required to maintain the horizontal open hole section of the well close to the top of the reservoir, within a window of 3 ft.The horizontal sections were drilled using real-time data transmission, geosteering and logging while drilling technology. This collective approach required support from a dedicated team of geologists that was in permanent contact with directional drillers and drilling engineers through a special online platform. The geosteering team requested adjustments to the well trajectory based on real-time logging data transmitted from the rigs.Directional wells drilled with motors are drilled with drillstring rotation (rotating mode) are not required when corrections in well trajectory, and without drillstring rotation (sliding mode) when a change or adjustment to the well trajectory is needed. Conventional drilling in sliding mode is much less efficient than drilling in the rotating mode. In the sliding mode, the motor must be oriented before a slide can begin; orienting the motor involves two steps. First, the drillstring must be oriented in the required direction; it is rotated gradually to place the motor bend in the desired direction. Second, as the bit direction is being established, the torque has to be released from the drillstring so the bit orientation will stay relatively constant. If the torque is not worked out of the drillstring, it may cause the tool face orientation to change as the drillstring is advanced for drilling. The bit is initially pointed in a direction clockwise from the desired drilling direction, thereby counteracting the reactive torque of the motor. This process is often difficult and inefficient to implement1.Based on an analysis of approximately 280 horizontal wells drilled with steerable motors in Khurais field, it was found that approximately 30% of the drilling time was spent in the sliding drilling mode. In a sliding mode, hole cleaning is less efficient because there is no pipe rotation and cuttings accumulate on the low side of the hole and produce excessive friction that makes it progressively more difficult for the drillstring to slide smoothly. This friction also makes it difficult to keep a constant weight on the bit (WOB); consequently, the stalling of the steerable motor becomes an issue. Maintaining an acceptable rate of penetration (ROP) while preventing the motor from stalling requires that the motor be operated in a narrow load range. To minimize the problems with maintaining WOB and preventing motor stalling, roller cone bits were used in the Khurais project. Rotary steerable systems (RSSs) with point-the-bit technology were also utilized in the Khurais project. This technology was only used to drill the last part of the extended horizontal sections, when it was difficult to continue drilling with steerable motors due to the high friction that made the sliding process very difficult. The cost of RSS tools is much higher than that of the conventional steerable motors; the new technology presented in this article allows the drilling of higher horizontal displacements with conventional steerable motors, thereby minimizing the overall directional drilling costs.BRIEF DESCRIPTION OF THE STANDARD DRILLING PROCESSThe directional drilling plan for a typical Khurais well requires landing the 7” liner on top of the reservoir at 88°. The 6?”horizontal section is drilled to 89° at a 2°/100 ft buildup rate, and the angle is held to total depth (TD) at approximately14,000 ft measured depth (MD). To maintain the well trajectory in a window of 3 ft close to the top of the reservoir, a series of rotating and sliding intervals is required, following the instructions of the specialized geosteering center.Tool face orientation can shift with changes in WOB and torque; as weight is applied to the bit, torque at the bit increases. Therefore, the overall gross ROP is much less during sliding mode with a steerable motor than during rotating mode. It is not unusual to have the sliding ROP be as much as 70% less than the rotating ROP2.To execute a slide, the driller normally stops drilling, picks up the drill bit off the bottom and reciprocates the drillstring to release trapped torque. The downhole motor, with its bent housing approximately 7 ft above the bit, experiences an equal force in the opposite direction (left) of the bit rotation, called reactive torque. To compensate for the effect of the reactive torque on the bit, the driller then must reorient the tool face (clockwise) and control the slack off at the surface to achieve the desired tool face angle. The average clockwise direction compensation required was about 40° in the wells drilled in Khurais field.Weight is transferred to the bit by slacking off at the surface. The difference between the weight that the bit actually receives and the amount slacked off at the surface is the drag force that opposes pipe movement. Controlling bit weight in the sliding mode is difficult because of the friction (drag) in extended sections, which can cause the WOB to be released suddenly. If asudden transfer of weight to the bit exceeds what the downhole motor can handle, the motor will stall and the bit rotation will come to a sudden halt. Such stalling conditions can damage the rubber of the steerable motor stator; the amount of damage depends on the amount of the weight transferred to the bit and the number of times the motor stalls. Sudden transfers of weight to the bit are often difficult to prevent1, 2.In conventional sliding mode, achieving the proper orientation of the tool face becomes more challenging the more that the horizontal departure increases because of the increased difficulty in eliminating torque from the system during initial reciprocations. Once a proper tool face orientation is achieved, maintaining that orientation alsobecomes more difficult with increasing horizontal departuresstatic friction above the section influenced by the motor torque. This static zone provides rotational stability for the motor tool face in much the way that a keel stabilizes a ship.In practice, the optimal oscillating torque applied to the drillstring is determined dynamically at the rig rather than through calculations.DESCRIPTIONThe sliding automation technology consists of software and hardware components. The software component receives three main inputs; information from a manual input screen, surface torque from the top drive and standpipe pressure (as an indication of reactive torque). During the rocking cycle, the system permanently fine-tunes the amount of surface torque applied to the right and left to correct for the change inreactive torque. To orient the tool face during a rocking cycle,the directional driller can change the direction of the tool face by applying toque pulses to the right or to the left. Thehardware component is a robotic control system that can be installed in any type of top drive. This surface control system interfaces with the top drive control system and works by rocking the top of the drillstring alternately clockwise and counterclockwise, so the upper part of the drillstring always experiences tangential motion.BENEFITS OF THE AUTOMATED TORQUE CONTROL SYSTEMUsing the rocking action applied with this system, the drillstring behaves as if it were rotating, and the slidingprocess is much more effective. The automated slide drilling allows substantial increases in both the daily footage drilled and the length of a horizontal section that can be drilled with a conventional steerable motor. The system adjusts the amount of surface torque needed to transfer the proper amount of weight to the bit and eliminates the need to pick up the drillstring off the bottom of the hole to make tool face corrections. Corrections in the tool face angle are easily achievedthrough additional torque pulses (bumping) during therocking cycles. The left-and-right torque rocking initiated by the top drive reduces longitudinal drag in the wellbore,allowing the drillpipe to rotate from the surface down to a point where torque from rotational friction against the side of the hole stops the drillpipe from turning.To commence slide drilling from the rotary drilling mode,the driller simply initiates an automatic rocking action by applying torque to the right and then to the left enough toallow appropriate weight transfer to the bit. The transfer of weight is controlled through automatic adjustments of rocking depth, which compensate for changes in reactive torque 1.FIELD TEST RESULTSFigure 3 shows the directional path of a typical well drilled in the Khurais field. The 6?” horizontal section had anbecause the weight transfer to the bit becomes more erratic,thereby affecting the reactive torque, and consequently changing the tool face angle 1. The solution to this problem,Fig. 2, describes a sequence of steps to illustrate how the new slider system works.NEW STEERABLE MOTOR CONTROL SYSTEMSaudi Aramco’s drilling team and the protect team selected candidate wells for testing the new sliding technology, which consists of a surface control system that interfaces with the top drive control system to overcome many of the friction related problems of steerable motors.The system works by rotating the top of the drillstring,alternately clockwise and counterclockwise until predetermined surface torque values are achieved; in this way, the upper part of the drillstring always experiences tangential motion. The amount of cyclical torque applied at the surface depends on the particular frictional characteristics of the well. This method keeps drillstring friction in the dynamic mode and significantly reduces axial friction. The amount of cyclical torque applied at the surface depends on the particular frictional charac-teristics of the well. By sensing the amount of surface torque needed to transfer the proper amount of weight to the bit, and eliminating the need to bring the drillstring off the bottom to make tool face corrections, automated slide drilling allows substantial increases in both the daily footage drilled and the length of horizontal sections that can be achieved 1, 2.Subsequently, there is no time lost in orienting the tool face,as compared to the conventional method of changing modes.Through manipulation of the surface torque oscillations,the driller can move the point of rocking depth as deep along the drillstring as desired. The slider control system uses this principle to improve the performance of drilling with steerable motors. The system drives the point of influence deep enough to significantly reduce the axial friction that causes stick/slip during sliding.The depth to which the point of influence is driven islimited by the fact such that a section of drillstring remains in Fig. 2. Illustration of how the new slider technology works. extension of 8,460 ft from a 7” liner shoe: 5,889 ft to 14,350ft. The liner shoe was set to an inclination of 85°. The section was drilled with a steerable motor and without slider tech-nology from the liner shoe to 8,828 ft MD. When the well reached 7,000 ft, a severe loss of circulation zones was encountered, and mud returns were only 20%. Under this situation, due to the poor hole cleaning of conventionalsliding mode, cuttings began to accumulate in the low side of the lateral. The drilling process continued with water and gel sweeps, but at 8,828 ft MD, the conventional sliding drilling process became extremely difficult due to severe drillstring friction. The operator decided to install the new slider system afterwards to address the excessive friction issue. The slider system was utilized to drill almost 4,000 ft of the horizontal section from 8,828 ft MD to 12,888 ft MD with only 20%mud return. Despite these severe hole conditions, the sliding drilling was carried out successfully.Figure 4 shows the overall ROP (sliding and rotating) for both sections drilled with the same bottom-hole assembly (BHA) and a similar type of tricone roller bit. The overall ROP in the section where the slider system was used is higher in spite of the additional horizontal departure.At 12,888 ft MD, after a vertical departure of almost 8,800ft, the drilling team decided to utilize a RSS due to the extremely high frictions.The slider system was also utilized to drill the multilateral Well B. In this well, the 7” liner was set at 7,850 ft with 85°inclination, and the 6?” horizontal motherbore section was then drilled to 9,536 ft, where it became very difficult to slide with an acceptable ROP; at that point it was decided to install the slider control system. The drilling continued with the utilization of the slider control system until the TD of the motherbore at 12,070 ft was reached.A section that was drilled without the assistance of theslider system where the tool face was unsteady and difficult to control due to reactive torque and stalling of the steerable motor is shown in Fig. 5. A plot from a section drilled with the slider, Fig. 6, shows a steadier tool face as a result of the elimination of motor stalling and achievement of smooth WOB due to the slider’s rocking action.Figure 7 shows the ROP while sliding with the slidersystem vs. the ROP while rotating; both are in a comparable range. If the slider had not been used, the sliding ROP would have been approximately 30% of the rotating ROP . A greater sliding ROP is another benefit of this technology.From the information tracked in drilling morning reports and on the directional driller parameter sheet, the teamdetermined that the distribution of the drilling time when the slider system wasn’t used was 60% sliding and 40% rotating,but with the utilization of the slider system, the ratio changedFig. 3. Interval drilled with slider shows severe mud losses and higher ROPcompared to interval drilled without slider.Fig. 4. Comparison of ROP under similar conditions with slider (green bar) andwithout it.Fig. 5. Section drilled without slider where tool face was difficult to control.Fig. 6. Section drilled with the slider where tool face was controlled.required to orient the tool face, and the bottom chart shows that drillstring pickups were not necessary when the slider was used.CONCLUSIONSThis new technology proved that it is possible to overcome the friction related problems of steerable motors by rotating the drillstring alternately clockwise and counterclockwise, so the upper part of the drillstring always experiences tangential motion. This technology allows the transfer of weight smoothly to the bit, thereby eliminating motor stall. The sliding ROP was increased by 70% in some cases. The slider system ensured a very steady tool face and showed anexcellent capability to correct the tool face angle wheneverto 25% sliding and 75% rotating. This reduction in percent-age of sliding time is mainly due to the increase in the ROP achieved during sliding mode while using this new technology. In Well C, the drilling team decided to drill intervals alternately with and without the slider, with the objective of comparing the benefits of this new technology under the same hole conditions and using the same BHA design. The 7” liner was set at 6,200 ft MD and at an inclination of 84°; after drilling the 6?” section to 7,737 ft, the driller started utilizing the slider system.Comparable sliding ROPs are shown in Fig. 8. With the use of the slider, the average improvement in the sliding ROP was approximately 60%.In Fig. 9, a comparison of drilling parameters (blockposition and pump pressure) in two sections drilled in sliding mode with and without the slider is shown. The top chart shows motor stalling and drillstring pickups due toinefficient transfer of weight to the bit, the bottom chart shows that with the assistance of the slider system, no drillstringpickup was required and no pump pressure spikes were experienced.In Well D, the slider was used to drill the whole horizontal interval from 6,200 ft MD to 11,213 ft MD. At 9,500 ft, the drag reached 45,000 lbs, but rocking the drillstring with the slider was effective in overcoming the friction and minimizing pipe buckling to effectively transfer weight to the bit.Figure 10 shows two charts. The top chart represents themanual sliding section, showing the drillstring pickupsFig. 7. Sliding ROP using the slider compared to rotating ROP.Fig. 8. Sliding ROP in different sections drilled alternately with and without the slider.Fig. 10. The top chart shows drillstring pickups during manual slide drillingwithout the slider. The bottom chart shows that no drillstring pickups were needed when the slider was used.Fig. 9. Comparable performance during sliding drilling without the slider and with it.required, and it provides a means to correct the tool face orientation while sliding.The success of the slider depends on the proper training of the directional drillers and ensuring they use it in the way it was designed to be used. The training usually takes 3? hours, and it is recommended that training occur away from the rig. Nothing goes downhole, so there are virtually no failures.ACKNOWLEDGMENTSThe authors would like to thank the management of Saudi Aramco for their support and permission to publish this article.This article was presented at the SPE Saudi Arabia Section Technical Symposium and Exhibition, al-Khobar, Saudi Arabia, May 15-18, 2011.REFERENCES1.Maidla, E. and Haci, M.: “Understanding Torque: TheKey to Slide Drilling Directional Wells,” IADC/SPE paper 87162, presented at the IADC/SPE Drilling Conference, Dallas, Texas, March 2-4, 2004.2.Maidla, E., Haci, M., Jones, S., Cluchey, M., Alexander,M. and Warren, T.: “Field Proof of the New SlidingTechnology for Directional Drilling,” IADC/SPE paper 92558, presented at the IADC/SPE Drilling Conference, Amsterdam, the Netherlands, February 23-25, 2005.Abdullah has worked on various fields and increments. Currently, he is handling the Ghawar Lump Sum Turn Key Waleed G. Kotbwith the Wildcat Oilfield Services. Hehas 9 years of experience in the oil andgas industry on both land and offshoredrilling rigs. Waleed joined Wildcat in2005 as a Senior Service Engineer andprogressed on to become the Saudi Arabian area Service Supervisor before moving to hisAbdelsattar H. El-GamalWildcat Oilfield Services in 2006 as aSenior Engineer and then became theCorporate Service Manager in 2007.He is responsible for managing ahighly evolving service teamcomprising junior and senior engineers, team leaders and coordinators who work in a diverse number of highly innovative equipment andRoberto H. Tello Kragjcek joinedSaudi Aramco in 2006. Since then, hehas worked in Ghawar field and onthe Khurais project. Roberto has 16years of drilling and completionengineering experience in major oilcompanies. Before joining Saudi Aramco, he worked for Chevron-Texaco as a DrillingEngineer Supervisor. Roberto has been involved in drilling projects in Venezuela, the United States, Trinidad and Tobago and Argentina. Recently he was also involved inthe preparation of lump sum drilling contracts for Ghawar field, drilling technical limit, bit design optimization and mud plant facility installation, among others.In 1994, Roberto received his B.S. degree in Mechanical Engineering from San Juan University, San Juan, Argentina. Currently he is completing his M.S. degree in PetroleumEngineering in Heriot-Watt University, Edinburgh, U.K. BIOGRAPHIES。

沙特KHRS307井钻井技术应用

ＫＨＲＳ地区是沙特阿拉伯东南部油气田中储量较为丰富的区块。自２０下半年，所属中石化的０７年
中国钻井队开始在该区块施工生产井。经过不断吸取经验和研究分析，总结出一套包括边漏边钻、柴油乳化泥浆体系、双级固井等相关钻井技术，较好地解决了施工中存在的风险。ＫＨＲ３７是阿美石油・Ｓ０井公司在ＫＨＲＳ地区部署的一口重要生产水平井，设计井深３５ｍ，设计周期２ｄ３０１。在施工过程中，由
沙特ＫＨＲ３７井钻井技术应用Ｓ０
张忠涛，何成刚（南石油勘探局河钻井工程公司，河南南阳１３３）７１２
王惠卫（油田分公司河南第一采油厂，河南南阳４３２７１）３
张海潮，陈浩，朱强（河南石油勘探局钻井工程公司，河南南阳４３３）７１２
压力小，地层被压漏，一般情况下，这个薄弱点都靠近钻头处。在发生突然全部漏失后，如果保持钻具
不动或是继续钻进，上部岩屑随着钻井液下落，在扶正器、钻头上部会滞留一部分岩屑，随着时间的推移，滞留量会越来越多，形成砂桥，而泵入的钻井液又无法到达这个部位，最终造成沉砂卡钻。随着井眼内的钻井液漏失，上部较松软地层因为泥饼胶结不好，在重力的作用下，可能导致岩石脱落或是大面积垮塌，这种现象表现为上提扭矩增大，悬重增加，下放钻具扭矩变小。］
石油天然气学报（汉石油学院学报）江

沙特HRML地区钻井工艺技术

３２在三开阶段，井中基本都会遇到溢流，流．钻溢量很大，是关井求压时关井立压和套压读数都为但
零，加了压井困难和成本。增
２２井身结构（表２．见）３ＨＲＭＬ地区钻井难点
号钻井队在本区块共完成了４口井的钻井作业，通过对钻井过程中出现的问题进行不断的研究和总结，决了本区块钻井过程中产生的技术难题，握解掌了应对工艺技术措施。为我公司和沙特阿美公司今后在ＨＲＭＬ油田的钻井作业提供了宝贵的技术资料和经验。２沙特ＨＲＭＬ地区的地层岩性和井身结构２１ＨＲＭＬ地区的地质分层及岩性（表１．见）表１沙特ＨＲＭＬ区块地层分层与地层岩性
１概述沙特阿拉伯是世界上原油储量最丰富，量最产多的国家，年的原油产量约占世界原油产量的１每／４近年来随着世界石油价格的持续上涨，特阿美沙
公司为了保证原油产量，老油田持续开采的基础在上，始开发新的区块。ＨＲＭＬ油田是阿美公司２开Ｏ多年前勘探存放，目前重新投入开发的油田。程中产生的技术难题，握了应对工艺技术措施。为我公司和沙特阿美公司４后在掌－

沙特阿拉伯UTMN油田水平井钻井技术!!!

沙特阿拉伯UTMN油田水平井钻井技术提要：本文从水平井的轨迹控制技术、钻井液技术、井控及H2S防护、井下安全等到几方面，论述了沙特阿拉伯UTMN油田水平井钻井技术，并从中得出了一些认识。

对今后在该地区及中东其他地区钻井都具有一定的参考价值。

关键词：水平井钻井、钻井液、井控、H2S防护、井下安全、沙特阿拉伯UTMN 油田一．概述：沙特阿拉伯UTMN油田位于沙特阿拉伯的中部，属于热带沙漠气候。

近年来的开发井型为基本为水平井（包括新钻水平井和套管开窗分支水平井）其基本井身结构为：开窗井：井身结构同上，7”套管开窗钻6 1/8”或5 7/8”井眼裸眼完井或7 “套管开窗，造斜段6 1/8”或5 7/8”井眼裸眼完井；二．地质特性该地区是一个海相沉积的油田，地层为中生代和新生代，以石灰岩和硬石膏地层为主，主力油层在阿拉伯“C”和阿拉伯“D”地层。

从岩性特证上看，上部地层多为松软的白云岩和少量的页岩以及少量的石灰岩，下部地层多为石灰岩、硬石膏和砂岩。

但由于地层压力梯度各层厚不等。

井漏上、井涌时有发生，并且某些区块产层含有H2S气体，因此对井控及防H2S的要求非常严格。

三．水平井钻井技术（一）技术1．设计内容极为复杂。

如：地流产数的计算，井口经纬度的计算，井口坐标采用网格坐标等；某些井为多靶点绕障水平井，由于地层层位客观要求，耙点垂深和方位均是变化的，需考虑的因素较多，给设计和施工造成了很大的困难。

2．水平段轨迹控制要求十分严格。

要求轨迹控制在上下2英尺的范围。

对于水平段超过千米，控制范围精度如此苛刻的井眼的安全施工是一个巨大的挑战。

3．长水平段钻进，由于钻具与井壁之间摩阻力，扭矩较大，造成控制过程中摆放工具装置角十分困难。

4．多层位产层对井身轨迹造成不利的影响。

UTMN油田主力油层为阿拉伯C和阿拉伯D地层，其中阿拉伯C又细分为多个层位，各层位之间夹杂有较硬地层。

某些水平井需穿越多个层位，由于层位之间的岩性不一样，软硬交错，使钻头在钻进过程中受力不均，给轨迹控制带来了相当的难度。

探索沙特阿拉伯恶劣自然环境下的钻修井设备管理方法及应用

探索沙特阿拉伯恶劣自然环境下的钻修井设备管理方法及应用作者：王英杰焦天津来源：《中国科技博览》2016年第08期中图分类号：TE935 文献标识码：A 文章编号：1009-914X（2016）08-0290-01一、项目提出的背景及主要原因中东沙特阿拉伯钻修井项目多位于是沙漠地区，为热带沙漠性气候，气候干燥，降水集中在冬春季，其余季节几乎无降水，日夜温差大，夏季气温高（气温最高时地表温度达到70℃）风沙大，冬季气温最低达到1℃左右。

当地水质为富含矿物的咸水，多硫化氢。

面对这样的气候我们在两年多的施工过程中摸索出一套适应该地区该区块的设备管理方法，确保了设备的正常运转。

二、项目主要内容及实施情况面对这样的气候我们在两年多的施工过程中摸索出一套适应该地区的设备管理方法，确保了设备的正常运转。

这套管理方法可以总结为防、查、改、换四个字。

一、防：我们在执行各项设备管理规定的前提下，根据沙特的实际情况我们重点提出了防风沙、防高温、防水垢等四防措施。

1、防风沙：沙特地区夏秋季节风大沙大，而地面都是细沙，一起风眼耳口鼻到处进沙，设备的缝隙、呼吸器进入的沙尘很多。

我们提出风季重点防风沙，每天不定时检查、清理、疏通空气滤芯散热水箱呼吸器设备缝隙。

加装绞车风机防沙槽，柴油机防沙房，空调防沙滤网，尽最大的可能清理沙尘，保证设备的正常运转。

2、防高温：沙特地区夏季温度高，空气中水分少，使设备散热困难，液压油和润滑油变质快，盘刹等设备液压密封件由于环境温度经常超过60℃使用寿命大幅缩短，柴油机水温居高不下等问题成为困扰施工的难题。

我们采用为钻机、柴油机、SCR房、钻井泵搭建防照棚减少直射降温，钻井泵、柴油机强制水循环降温，加密检查缩短检修保养时间等措施保证了设备在高温下的正常运转。

3、防水垢：沙特当地水质富含矿物质，使用中管线内、设备内容易结水垢，我们对水源进行分类使用，选用百里之外矿物质含量低的水源，并对使用的水进行药物处理，防止水垢的形成。

中东沙特地区复杂地层钻井液适应性分析与应用

中东沙特地区复杂地层钻井液适应性分析与应用摘要：沙特区块存在流沙层、石膏层、完全漏失层、易塌易卡的泥岩层、高压盐水层、含硫化氢层、高温高压气层，因此对钻井液的要求高。

根据地层情况在上部大井眼流沙层施工中，使用高浓度膨润土一聚合物钻井液；在软泥岩、砂泥岩、石膏层施工中，使用高膨润土含量的KC1-PHPA不分散钻井液；在白云岩完全漏失层施工中，采用清水盲钻技术；在深部地层使用无膨润土相KC1抗温钻井液；使用含有随钻堵漏剂的堵漏浆进行随钻堵漏，保证了该区块强渗漏性砂岩地层的正常钻进。

现场应用结果表明，该套钻井液体系具有性能稳定、抑制性强、润滑性能好的特点，携岩洗井效果好，可有效防止钻井液对疏松地层井壁的冲刷，维护井眼稳定，并具有良好的防塌效果，抗盐、抗钙、抗硫化氢污染能力强，保证了深部复杂地层的快速钻进，满足了沙特B区块复杂地层钻井的要求，有效提高了钻井速度。

关键词：水基钻井液；井眼稳定；抗污染；井眼净化；沙特B区块沙特王地区地层复杂，钻井周期长，勘探开发难度大，没有取得实质性进展。

随着近年油价上涨和钻井技术的进步，对该区块进行风险勘探开发。

B区块表层复杂，采用大量技术套管封固复杂地层，以保证顺利钻达目的层。

1 钻井液技术难点1）上部地层。

沙特B区块井深0～200 m为流沙层，井深200- 600 m 为严重水敏性的砂泥岩层，井深600～800 m为纯石膏层，井深800～1100 m为裂缝发育的灰岩、白云岩地层，井深1100～1 500m为水敏性强的淤泥层和易坍塌掉块的硬脆性泥岩层。

施工中均发生表层套管遇阻、遇卡的情况。

在流沙层钻进时，井壁极易坍塌，导致下表层套管困难和卡套管事故不断。

严重水敏性的砂泥岩地层极易发生钻头泥包，影响钻井速度及井下安全。

在较纯石膏层钻进时，钻井液不同程度地出现石膏污染，引起钻井液流变性变差，滤失量变大，泥饼质量变差等复杂情况。

所有的井在上部白云岩地层都发生过井漏，漏失段长达300 m，漏失速度从渗漏到有进无出，使用随钻堵漏、桥塞堵漏、静堵、水泥堵漏等方法均无效。

沙特阿美公司KHRS区块完井工艺技术

沙特阿美公司KHRS区块完井工艺技术
沙特阿美公司KHRS区块完井工艺技术
于军泉;安玉秀;王富群
【期刊名称】《钻采工艺》
【年(卷),期】2008(031)006
【摘要】沙特阿拉伯KHRS区块(以下简称KHRS区块)的油藏压力只有12.5MPa左右,无法满足自喷采油的要求.在2007年7月份开始的第一轮生产井的完井作业中,阿美公司主要使用全油基泥浆完井液,采用了Zenith电潜泵(ESP)举升完井.油基钻井液密度低、润滑性能好,且不和岩石发生反应,有利于水平井水平段钻具钻压、扭矩的输送,不易和引起低压油藏的漏失,降低油藏污染.KHRS区块采用的ESP可以实现可变驱动速度、实时井下监测,可用于高含水量、高气油比、高PI指数的油井开采,提高开采产量.阿美公司在沙特阿拉伯KHRS区块制定了严格的完井工艺.通过连续几口井作业,总结了阿美公司KHRS 区块完井作业程序,分析了ZENITH电潜泵的下入特点及注意事项,对电潜泵完井工艺的设计及实施作业有一定的参考价值.
【总页数】3页(31-33)
【关键词】井身结构;洗井;封隔器;完井
【作者】于军泉;安玉秀;王富群
【作者单位】中原石油勘探局对外经济贸易总公司;中原石油勘探局对外经济贸易总公司;中原石油勘探局对外经济贸易总公司【正文语种】中文
【中图分类】TE257
【相关文献】。

沙特B区块复杂地层钻井液技术

沙特B区块复杂地层钻井液技术沙特B区块复杂地层钻井液技术论文摘要本文主要探讨了沙特B区块复杂地层钻井液技术的发展。

首先，介绍了该领域的研究背景和现状，接着，分析了复杂地层钻井液技术的现状和发展方向。

然后，阐述了如何改进钻井液的配方和加倍工艺参数，以解决不同的井壁稳定性问题。

最后，对未来的发展趋势进行了展望。

关键词：沙特B区块；复杂地层；钻井液技术；稳定性；配方引言随着国内外油田勘探与开发工作的不断深入展开，钻井液技术发展成为支撑整个勘探开发工作的关键技术之一。

钻井液作为钻井过程中的重要组成部分，对井下作业的成败有着至关重要的影响。

然而，在沙特B区块这样复杂地层中，往往会遇到很多技术难点。

例如，井壁稳定性问题、地层透水性不可避免的影响了钻井液技术的应用。

如何应对这些挑战，保证钻井液技术的稳定性和可靠性，成为当前沙特B区块复杂地层钻井液技术研究的主要目标。

一、深化复杂地层钻井液技术研究复杂地层钻井液技术在沙特B区块应用时，存在着很多不确定因素，如地下水、地层水溢等。

考虑到钻井液的稳定性、可靠性和经济效益，有必要对复杂地层钻井液技术进行深入研究。

针对复杂地层的特点，可以采用先进的数值模拟和实验方法，对钻井过程模拟研究和有效性进行评估，提高钻井液开发和应用的水平。

二、改进钻井液配方钻井液的配方是沙特B区块复杂地层钻井液技术的重要组成部分。

通过改变钻井液配方的成分、浓度和类型，可以有效地控制井壁稳定性问题。

在选择钻井液成分时，应注意其对地层物质的侵蚀和腐蚀。

针对当前存在的问题，需要改进钻井液配方选择，并以此为基础对钻井液的加料配比进行调整。

三、加倍工艺参数除了改善配方，还可以通过加倍工艺参数，提高复杂地层钻井液的适应性。

加倍参数可以使钻井液的性能更加完善，从而达到更好的稳定性。

加倍参数不仅可以改变钻井液的性质，也可以改变其特征和比较性能，从而满足特定需要。

四、展望未来，随着石油勘探和开发工作的不断深入，沙特B区块复杂地层钻井液技术在钻井过程中将扮演更加重要的角色。

沙特阿美公司钻修井技术应用

沙特阿美公司钻修井技术应用[摘要] 沙特阿美公司是一个有60多年历史的综合国际石油公司，是世界最大的石油生产公司和世界第六大石油炼制商，拥有世界最大的陆上油田和海上油田。

其凭借雄厚的经济实力和广阔的市场，汇聚了国际上大多数跨国石油服务公司，许多最先进的工艺技术往往都是在阿美公司开始运用，并发展成熟起来。

因此有人说沙特是高新技术的演兵场，一点也不为过。

通过对沙特阿美公司钻井和钻修井技术应用的介绍，希望对国内钻修井工艺有一定的参考借鉴作用。

[关键词] 沙特阿美公司钻井工艺钻修井工艺1.前言沙特阿拉伯的油田是海相沉积的油田，地层为中生代和新生代，以石灰岩和硬石膏地层为主，主力油层在阿拉伯“C”和阿拉伯“D”地层。

从岩性特征上看，上部地层多为松软的白云岩和少量的页岩以及少量的石灰岩，下部地层多为石灰岩、硬石膏和砂岩。

但由于地层压力梯度各层厚不等，井漏、井涌时有发生，并且多数区块产层含有H2S气体，因此对井控及防H2S的要求非常严格。

沙特阿美公司是一个有60多年历史的综合国际石油公司，是世界最大的石油生产公司和世界第六大石油炼制商，拥有世界最大的陆上油田和海上油田。

因此有人说沙特是高新技术的演兵场，一点也不为过。

通过对沙特阿美公司钻修井技术应用的介绍，希望对国内钻修井工艺有一定的参考借鉴作用。

2.钻修井工艺2.1 开钻井口检查开钻后，检查所有井口压力，以及所有井口设备是否处于良好的工作状况。

检测井内压力和确认井内各层套管之间的密封是否失效，为后来的固井及井口转换工作提供依据。

2.2 压井作业沙特油区地层多为高含硫地区，地层孔隙度大，渗透率较好，稳定性也较强，所以开钻压井都是采用硬压井。

由于TCA 内在开钻初期是密闭的，所以开钻首先从油管内进行压井。

待井内压力达到平衡，进行钢丝作业，下塞子封住地层压力。

沙特KHRS地区16″井眼钻井及固井技术

沙特KHRS地区16″井眼钻井及固井技术
张海潮;张忠涛;王凯;李伟;高书从;陈浩
【期刊名称】《石油地质与工程》
【年(卷),期】2008(022)004
【摘要】介绍了在沙特HKRS地区对16″井眼进行钻井和固井的施工工艺,分析了行之有效的清水钻井配合高粘泥浆技术、灌泥浆帽技术、水泥伞和顶部固井技术.这些技术的推广应用,极大地缩短了钻井周期,同时对国内类似复杂地层钻进具有重要的借鉴意义.
【总页数】2页(P82-83)
【作者】张海潮;张忠涛;王凯;李伟;高书从;陈浩
【作者单位】中国石化河南石油勘探局钻井工程公司,河南南阳,473132;中国石化河南石油勘探局钻井工程公司,河南南阳,473132;中国石油长城钻探工程公司;中国石化河南石油勘探局钻井工程公司,河南南阳,473132;中国石化河南石油勘探局钻井工程公司,河南南阳,473132;中国石化河南石油勘探局钻井工程公司,河南南阳,473132
【正文语种】中文
【中图分类】TE242
【相关文献】
1.小井眼开窗侧钻井固井工艺技术探讨 [J], 李相鹏
2.小井眼开窗侧钻井固井工艺技术 [J], 刘双进
3.长庆油田套管开窗侧钻井小井眼窄间隙固井技术 [J], 刘志雄; 刘克强; 胡久艳
4.小井眼开窗侧钻井固井工艺技术探讨 [J], 马邦
5.沙特KHRS307井钻井技术应用 [J], 张忠涛;何成刚;王惠卫;张海潮;陈浩;朱强因版权原因，仅展示原文概要，查看原文内容请购买。

哈萨克斯坦科扎萨伊油田优快钻井技术

位于哈萨克斯坦滨里海油区，地
质储量丰富，上部地层属古生代二叠系，下部储层为石炭系浅海碳酸盐岩，含油层系主要是石炭系 KT⁃Ⅱ ，岩性为灰岩，少量泥岩。主力储层埋深 2900~3500 m，非均质性强，属低孔、中低渗碳酸盐岩底水油藏，主要开发井型为直井和定向井。
地层岩性复杂。上二叠系地层岩性混杂，泥岩、砂岩、灰质泥岩、砾岩、石膏等频繁交替，部分井段夹层多，蹩跳钻严重，严重影响钻头使用寿命，造
成频繁起下钻，断钻具及钻头故障时有发生，采用降转速、降钻压的方法来减轻蹩跳钻，影响钻井速度，如 K 油田某口井在上二叠系地层钻遇多夹层，导致钻头损坏严重，单只钻头平均进尺仅为 24 m，平均机械钻速仅为 1.4 m/h。上部地层易斜，上二叠系地层部分井段存在地层软硬交错、地层倾角大、易产生井斜，采用降低钻压吊打的方式，机械钻速低，如 A 油田某井在上二叠系地层钻遇井斜控制难度大的问题，多次起钻换钻具组合并调整钻井参数，定向钻井比例达 40%，平均机械钻速低至 1.1 m/h，
Optimal and fast drilling technology for KOA Oilfield in Kazakhstan

地质钻探堵漏新技术的应用及效果分析

地质钻探堵漏新技术的应用及效果分析摘要：在地质钻探的过程中钻井液漏失会恶化孔内工况，钻井液正常循环被破坏，孔内压力失衡，易造成卡钻，烧钻甚至埋钻等严重事故，给施工单位造成严重的损失。

通过地质钻探取心，可直接揭露地层深部岩矿心性质，为地质找矿提供直观而准确的依据。

地层漏失是地质钻探施工过程中最常见的问题，对地质钻探工作有很大的影响，需引起地质钻探工作者的注意。

关键词：地质钻探；堵漏新技术；应用效果地层漏失是地质钻探，乃至石油、天然气、地热等所有钻探中经常遇到的共同问题。

据统计全世界油井井漏发生率占钻井总数的20%～25%，成为钻井中遇到的最为棘手的问题，造成钻井成本的大幅提高，常给施工者造成数以百万的经济损失。

地质岩心钻探虽然没有全面统计，但钻孔漏失仍然是制约提高钻探效率的主要瓶颈问题之一。

1发生地质钻探孔漏失的原因分析1.1渗透性漏失当地质层中的渗透性比较高，比如此类地质层是由粗砾岩、粗砂岩或者是含砂的岩层构成的，就极易在地质钻探时发生钻井液的漏失。

此种漏失称之为渗透性漏失。

当钻井液液柱压力的作用下，钻井液会渗透进地质层的空隙当中，此种漏失的速率较小。

1.2裂缝、溶洞类漏失当地质层中多为白云岩、石灰岩等，由于这类岩石会存在裂缝、溶洞，便会引起钻井液的漏失。

同时，如果存在地应力破碎带、断层等，地层压力小于钻井液液柱的压力而发生漏失现象。

此种漏失的速度较快，漏失量也较大，需要及时作出处理，否则将带来严重的后果。

1.3施工技术缺陷引起漏失在施工过程中出现技术上的不到位，或者直接发生技术失误，而引起地质钻探孔的漏失。

比如在施工过程中，造成地层压力与井底的压力出现明显的较大差别，其差值远远大出了钻井四周的挤压应力和地质层上的张力。

这样地层就很容易产生裂缝，引发地质钻探孔的漏失情况。

2堵漏技术研究现状经过几十年的研究摸索，国内外开发出了数百种堵漏材料。

依据其作用机理常用堵漏材料可分为6类，即桥接堵漏材料、高失水堵漏材料、暂堵材料、化学堵漏材料、无机胶凝堵漏材料和软（硬）塞类堵漏材料。

沙特多底分支水平井钻井技术应用探讨

沙特多底分支水平井钻井技术应用探讨【摘要】沙特油田是海相沉积地层,采用分支井钻井技术,在同一地层或不同产层内侧钻形成多底分支井眼,可大幅提高油气井产量,降低油气井综合成本。

目前主要形成套管自上而下开窗侧钻多底分支井、套管自下而上开窗侧钻多底分支井和裸眼水平段或大斜度段多次侧钻多底分支井等三种不同类型的多底分支井,在HRDH、UTMN等钻井区域的现场应用,取得良好效果。

【关键词】多底分支水平井可取式斜向器侧钻沙特根据地质结构条件和地层岩性特征,在同一主井眼系统内,采用分支井钻井技术,在同一地层或不同产层内侧钻形成多底分支井眼,可大幅提高油气井产量,降低油气井综合成本,是目前众多油田采用的先进技术之一。

沙特油田的区块都是海相沉积地层,地层为中生代和新生代,以流沙、白云质石灰岩、页岩和硬石膏为主,主力油层在Arab-C和Arab-D地层。

上部多为流沙和松软的白云岩、少量页岩及石灰岩,下部多为石灰岩、硬石膏和砂岩。

为最大限度提高油气井产量,沙特油田在主要油区采用分支井钻井技术,解决多底分支井钻井所面临特殊工具多、工序复杂;同一主井眼内存在多套地层压力系统,发生漏喷几率大等技术难点,主要形成套管自上而下开窗侧钻多底分支井、套管自下而上开窗侧钻多底分支井和裸眼水平段或大斜度段多次侧钻多底分支井等三种不同类型的多底分支井,在HRDH、UTMN等钻井区域的现场应用,取得良好效果。

1 不同类型多底分支井钻井技术1.1 套管自上而下开窗侧钻形成多底分支井多底井钻井涉及多方面的特殊工具,其中可取式斜向器是实现多次套管开窗侧钻的关键工具之一。

利用可取式斜向器在套管内多次开窗侧钻形成多个井眼。

HRDH-171井老井Φ473mm表层套管下深24.4m,Φ339.7mm技术套管下深638.11m,Φ244.5mm技术套管下深1115.55m,Φ178mm尾管至2245.12m,Φ155.5mm 井眼水平段至2907.31m,裸眼完井。

沙特ANDR-30井H2S泄漏和火灾事故应急救援技术应用

沙特ANDR-30井H2S泄漏和火灾事故应急救援技术应用杨红光【期刊名称】《当代化工》【年(卷),期】2012(41)7【摘要】On September 19th 2011, during operation of S&P 718 team of American oil company in ANDR-30 well, serious H2S leak and uncontrolled blowout happened. After the accident, Saudi Armco selected China SINO-15, Italy SP-201, Egypt DPS-46 three best teams to implement the rescue operation from three different directions, SP-201 team and DPS-46 team implemented conventional rescue drilling operation from east and north, respectively. SINO-15 team implemented the relief well drilling operation, ANDR-554 Well was a level sidetrack relief well arranged by Armco company, level sidetrack cut 7 "casing for accident well was carried out to implement the kill operation and balance formation pressure to control the well, at last safe fire fighting and controlling hydrogen sulfide leakage were fast achieved. Through the implementation of ANDR-554 relief well, the optimum position can be selected from lower strata directly, the most short window sidetrack rescue can be carried out, speed is fast, time is short, the bull 's-eye radius is small, precision of directional construction is high . After 36 days, the rescue mission was successfully completed.%2011年9月19日,美国石油公司普尔718队在ANDR-30作业期间,发生了严重的H2S 泄露和井喷失控着火.事故发生后,沙特阿美公司选出中国SINO-15、意大利SP-201、埃及DPS-46三支最好的队伍,从三个不同的方向同时实施救援作业,其中SP-201、DPS-46分别从东和北实施常规救援钻探作业,从9-5/8"套管逐渐贴近,然后开窗压井.SINO- 15实施钻修救援井作业,ANDR-554井是阿美公司针对事故井布置的一口水平侧钻救援井,为事故井水平侧钻切入7寸套管,实施压井作业,平衡地层压力控制井口,达到快速、安全灭火和控制硫化氢泄漏.通过实施ANDR-554救援井,直接从下部地层选取最优位置、最短距离开窗侧钻救援,速度快,时间短,靶心半径小,定向施工精度高,在全球开创了开窗侧钻点对点目标救援的先例,经过36天,成功完成救援任务.【总页数】3页(P714-716)【作者】杨红光【作者单位】中原石油勘探局钻井二公司,河南濮阳 457001【正文语种】中文【中图分类】TE687【相关文献】1.沙特多底分支水平井钻井技术应用探讨 [J], 隆新林2.高含CO2和H2S井测试工艺技术应用 [J], 李玉明3.打造港口危化品应急救援综合处置新模式--山东港口危险化学品泄漏爆燃事故应急救援综合演练记 [J], 王精堂;吕楠;刘德宝;陈业峰4.连云港港举行防泄漏火灾事故联合应急救援实战演习 [J], 孙永和5.沙特KHRS307井钻井技术应用 [J], 张忠涛;何成刚;王惠卫;张海潮;陈浩;朱强因版权原因，仅展示原文概要，查看原文内容请购买。