4FZ18-35-00四闸板液压防喷器设计(含15张CAD图纸)
4FZ18-35-00四闸板液压防喷器设计(含15张CAD图纸),FZ18,35,00,闸板,液压,防喷器,设计,15,CAD,图纸
外文翻译译文学生姓名: 院 (系): 专业班级: 指导教师: 完成日期: 深水防喷器组液压控制系统仿真Simulation of hydraulic control system of deepwater subsea blowout preventer stacks 摘要:井喷是海洋石油安全钻探生产的重要威胁,人为操作失误或元器件失效都可能 导致井喷。防喷器组(BOP) 安装在水下井口头,是控制井喷的核心部件,一旦发生 井喷,BOP控制系统驱动阀门关闭井口,保证油井的安全。研究了深水防喷器组包括 其液压控制系统的功能,在系统仿真软件Simulation X中建立防喷器组的详细模型, 包括环形防喷器和闸板防喷器及防喷器组的液压控制系统。仿真分析了1524 m水深下 防喷器在不同操作顺序下的封井过程,验证了BOP阀门关闭所用时间符合API规范要求, 仿真结果与平台实测数据基本吻合。关键词:深水防喷器组;深水钻井; 防喷器;液压控制系统;仿真Abstract: The oil and gas industry has been constantly affected by numerous blowouts since it was evolved. Blowout which is caused mainly by kick, leads to loss of valuable reserves and also causes property damage along with loss of life. Subsea blowout preventer(BOP) stack is the key equipment which ensures the safety of wellbore operation. Oncethe blowout occurs, the control system of BOP will actuate the corresponding valve and close the preventer within a specified time. This paper investigated the dynamic behavior of hydraulic control system of deep water subsea BOP stacks. Mathematic simulation models of the ram and annular preventers are established by using SimulationX software. Different cases are studied to verify whether it is appropriate to be operated according to API requirements at the water depth of 1524 m.Key words: Subsea BOP, Subsea drilling, Blowout preventer, Hydraulic control system, Simulation外文翻译译文:1引言闸板防喷器是油井控制装置的关键部分,主要用途是在钻井、修井、试油等过程 中控制井口压力。当井内有管柱时,配上全封闸板可全封闭井口,当处于紧急情况时, 可用剪切闸板剪断井内管柱,并全封闭井口。深水钻井防喷器系统在保障海上油气作 业安全,保护海洋环境和人身安全中起着关键作用。目前,国内深水钻井防喷器系统 研制正在起步阶段,为了能提高国产深水钻井防喷器系统关键设备技术水平,在介绍 深水钻井防喷器系统中关键设备的国内外技术现状基础上,重点对典型深水防喷器系 统中深水 BOP 组和控制单元的关键设备进行了研究。分析了深水防喷器系统中其关 键设备的主要特征,并对其组成和功能进行了说明。结合国内实际情况,提出了深水 钻井防喷器系统研究的建议。井喷在石油和天然气行业是一个对人类生命、经济损失或环境有潜在损害的风险。 过去已经有许多关于井喷事件对人类生活和环境造成了极大的损害的报道。大量的资 金和努力工作一直在研究如何防止井喷或限制它的损害达到最小。井喷主要是由于敲击造成的。在钻井期间,地层的压力应受到控制。地层压力可 以通过使用具有比地层流体密度更大密度的钻井液来控制。如果地层流体的密度高于 钻井液密度,地层流体可以进入井眼,并与钻井液一起循环,这可能为井喷铺路1。深海防喷器(BOP)系统在为深水区域的钻井活动提供安全的工作条件方面发挥 着极其重要的作用。水下防喷器组故障可能会导致灾难性事故,如深海石油钻井平台 深水地层的爆炸,以及2010年4月20日路易斯安那州沿岸的石油泄漏。深水地平台上 的海底BOP防喷器组被认为在爆炸前后隔离井失败。海底BOP可能在井喷之前有故障, 或者由于事故可能已经损坏2。在近期油气勘探和生产灾害之后,海底BOP系统的性 能评估可以得到认可。在海底相对简单经济的液压防喷器(BOP)控制系统必须由复杂且昂贵的多重电 气系统代替,其中液压信号以声速传播变得太长,以致在规定时间内执行功能。在海 底应用中,总运行时间(关闭或打开)BOP可以分为两部分:信号时间和填充时间。 信号时间是来自表面的导频信号到达海底控制舱中的相应阀门所需的上升时间。填充 时间是激活海底阀门和完全执行BOP功能之间的所经过时间。本文的目的是确定电-液多重控制是否可以应用于深度为1524 m的水。其他公司 以前进行的测试表明,精心设计的控制系统很有可能按照要求执行。API关闭时间为 闸板45秒,环形BOP为60秒。本研究的主要任务是为BOP闸板和环形功能建立数学模 拟模型,并根据API要求在1524 m水深进行适当的操作。所使用的软件是Simulation X,它是面向对象的程序,用于分析和优化流体动力 部件和系统的动态特性。液压模型元件的内置特征包括阀的非线性特性,执行器的机1械和体积效率,复合摩擦和止挡模型,以及真实的气体和流体行为。此外,它为海底 控制应用提供了一个定制的海底液压库。这允许在整个系统交互的分析中各个组件的 非线性动态和流动行为。2. 系统的描述海底BOP系统主要由海底BOP控制系统和海底BOP堆组成。典型的海底BOP系统 如图1所示。海底BOP控制系统包括表面和海底部件。位于钻机中的表面部件主要由中央控制 单元(CCU)组成,是控制系统的内核,具有全面的功能和压力调节能力。CCU是 基于微处理器的,并且通常使用三模块冗余(TMR)控制器来将命令从表面传输到 海底控制舱。控制系统的海底组件是两个完全独立的控制舱,海底蓝色舱和海底黄色 舱,可以对所有海底功能进行冗余控制。每个吊舱包括用于接收在表面上启动命令信 号的海底电子模块。由于钻井区域,海洋深度等方面的差异,海底BOP堆叠的构造有所不同。到目前 为止,还没有明确的配置标准。作为钻井过程中的二次障碍(主要障碍是钻井泥浆), BOP堆叠设计用于封闭井环或钻杆,采用两种防护剂,环形防护器和闸板防喷器,在 深水钻井过程中,BOP堆叠可以配备一个或两个环形防护器,但是BOP堆叠通常配备 四个或更多的闸板防喷器。不同的防水构造为海底BOP系统提供不同的性能水平。特 殊地,使用了一个剪切闸板防喷器剪切管道并密封井,这被认为是应急装置,如图1 所示,典型的海底BOP堆叠装有两个环形防护器和四个闸板防喷器,包括一个剪切闸 板和三个管柱。图1.海底BOP系统的典型架构3 海底BOP堆叠通常配有两个液压连接器:LMRP连接器和井口连接器。LMRP连接器位于两个环形防护器的中间,用于将LMRP连接到BOP堆叠。井口连接器用于将BOP堆叠连接到井口。 环形防护器、闸板防喷器、连接器以及诸如柔性接头、扼流器/压井阀和扼流/压井管线的其他部件被整合形成整个海底BOP堆叠。3. SimulationX中的系统模型SimulationX包含最常见的深水系统中包含的组件和阀门的通用模型库。此外, 它提供了许多基本的液压和机械元件,这使得可以容易设置定制的复杂模型,如海底 BOP堆叠系统。3.1 环形防喷器 环形防喷器可密封钻柱,套管或非圆柱形物体(例如凯利帽)周围。环形防喷器即使在钻孔期间旋转时也可有效地保持钻杆周围的密封。2环形防喷器使用楔形的原理将井眼关闭。图2显示了环形防护器的照片。它有一 个甜甜圈状橡胶密封圈,被称为弹性体包装单元,用钢筋加固。包装单元位于头部和 液压活塞之间的BOP壳体中。当活塞被制动时,向上的推力迫使包装单元收缩,密封 环空或裸井。环形防喷器使用“楔形”(锥形面)活塞。当活塞升高时,包装单元的 垂直运动受到头部的限制,活塞的倾斜面将密封单元向内挤压,朝向井筒的中心。在 活塞中作用在活塞上的力分别如图3所示。q3和q4分别代表工作压力和油井压力4。 图2.环形防喷器通过有限元法估算环形防护器中包装单元的弹性。 假设最后3的行程用于挤压 管道周围的包装单元。环形元件的活动轨迹如图4所示。 图3.环形防护器中的活塞图4.防护装置的压缩力图5给出了环形防护器的模型。该模型包括来自SimulationX库的元素,专门用于 液压、与机械库的元素相结合。环形防护器控制箱被简化为液压控制系统由必要的元 件组成,包括压力调节器,方向阀和软管管线。图5.环形防喷器的模型3.2 闸板防喷器 闸板防喷器在操作上类似于闸阀,使用一对相对的钢柱塞,闸板。闸板向井筒的中心延伸以限制流动或缩回以允许流动。闸板的内表面和顶面都装有压盖(弹性体密 封件),该密封件相对于井筒相对地压靠在井筒上,并且围绕穿过井眼的油管。图6 显示了一个典型的闸板防喷器。闸板有四种常见的类型,如管子闸板、半封闸板、剪切闸板和全封闸板。除了标 准的压头功能之外,可变孔径闸板经常被用作被称为堆叠测试阀的改进的防喷器装置 中的测试柱塞。用于深水应用的闸板防喷器通常采用液压驱动。螺纹轴通常仍然作为 锁定杆并入液压柱塞防护器中,作为在液压制动之后将冲头保持在适当位置的锁杆。 通过使用机械压头锁定机构,不需要保持恒定的液压。也可以使用其他类型的压头锁, 例如楔形锁。图6.闸板防喷器图7.闸板防喷器中的活塞图7 4中示出了在冲压防止器上施加的活塞压力。图8给出了一种防喷器的模型。 该模型采用楔形锁。闸板防喷器控制箱也被简化成包括必要元件的液压系统,包括压 力调节器,方向阀和软管管线。图8. 闸板防喷器的模型4.仿真结果本研究的主要任务是了解BOP堆叠在正常条件下的海底液压系统行为,并根据 API要求在水深1524 m下进行操作是否合适。API的闸板防喷器关闭时间为45秒,环 形防喷器为60秒。15评估系统与深水地平线相似。在水面上有三个液压泵提供所需的工作压力。刚性 导管线的长度为1524 m,外径为88.9 mm。LMRP蓄能器总的有效气体体积为908L, 预充气压力为27.6MPa。一个重要的问题是确定系统容量是否能够在所需的水深上串联或并联运行多个 执行器功能。模拟了防喷器不同操作顺序的情况,详细介绍了带时间图的结果。4.1 封闭上下环形防喷器串联 在这种情况下,当时间为2秒时,上环形防喷器(UAP)被制动以关闭。在其制动结束时,当时间为32秒时,下环形防喷器(LAP)开始关闭。控制箱中的压力调节 器设置为10.3 M Pa,增加了静压头压力。图9显示了两个环形防喷器的压力趋势和执行机构位置。从开始关闭到包装单元 到达管道的所需关闭时间被模拟为每个环形防护器的22秒。环形防喷器包装单元设置 为在行程最后3处关闭管道。那就是调节器压力再次开始上升的地方。LMRP蓄能器在20的表面预充氮气至27.6Mpa,并加入34.5MPa的静压头压力。 当两个环形防喷器运行时,LMRP蓄能器油量下降到最低294 L,包括3. 8 L死体积, 如图10所示。同时,供应压力降至最低43.3MPa。图9. UAP和LAP的压力趋势和执行器位置 图10.串联操作的LMRP蓄能器压力和油量 图11显示了来自三个表面HPU泵的泵流量,而两个环形防喷器串联运行。可以看出,在操作期间,三个泵都被启动。 图11.用于串联操作的表面泵流量 4.2 关闭并联式闸板防喷器UAP在这种情况下,当时间为2秒时,UAP被启动以关闭。在其制动结束时,当时间 分别为42秒和45秒时,LAP和一个闸板防喷器开始关闭。该运行顺序给出了最后一个 环形环形防喷器和闸板防喷器之间的平行操作。环形防喷器的压力调节器设置为与最后一种情况相同,而对于闸板防喷器,将其 设置为20.7 M Pa,增加静压头压力。图12显示了所有防喷器按预期运行,并没有防 止系统容量降低的迹象。图12.平行运行的压力趋势和执行器位置 当操作一个环形防喷器,紧接着是一个第二环形防喷器和一个闸板防喷器并联时,LMRP蓄能器油量下降到最小252 L,如图13所示。同时,供应压力下降到最小值35.4 M Pa图14显示出了来自三个表面HPU泵的泵流量,同时打开一个环形防喷器,随后是第二环形防护器和并联的闸板防喷器。可以看出,所有的三个泵开始并共同向系统提 供284L / min流量。图13.LMRP蓄能器压力和油量用于并联运行 图14.用于并联运行的表面泵流量其他情况也可以模拟,包括两个闸板防喷器和不同的操作顺序。类似的结果表明,所 有防喷器都可按预期运行,并没有防止系统容量降低的迹象。5结论建立一个完整的模型,以检查评估的海底液压系统是否适合根据API1524m水位 深度的API要求进行操作。仿真结果表明,根据API,环形和闸板防喷器的关闭时间 均小于规定值。此外,通过串联或并联运行,所有防喷器都可按预期运行,并没有防 止系统容量降低的迹象。这已经证明,所评估的液压控制系统适用于在1524 m的水深 下运行。参考文献1 Khan M F.关于防止井喷(失去敲击)的油井控制程序的重要审查D。加拿 大:达尔霍西大学,2010年.2 Harlow W F,Brantley B C,Harlow R M.BP深水地平线溢出后的初始影像修 复策略J。公共关系,2011,Rev.37, 80-83.3蔡宝平,刘Y H,Liu,Z K,et al等。 石油科学与工程学报2012(90/91):18 25.4孙 Z G.防喷器参数化设计与仿真技术研究D。北京:中国石油大学,2009.Simulation of hydraulic control system of deepwater subsea blowout preventer stacksMar. 2014 机床与液压 Hydromechatronics EngineeringVol. 42 No. 6 Received:2013-10-20 Fei GE,PhD.E-mail:gefeigsimx.com DOI:10.3969 / j.issn.10013881.2014.06.013Fei GE1, Hong GUO2 ,Bo LI2 ,Zheng XU1 1Great SimTechnoloby Co., Ldt.,Beijing 100036,China;2 China National Offshore Oil Corporation, Beijing 100027,ChinaAbstract: The oil and gas industry has been constantly affected by numerous blowouts since it was evolved. Blowout which is caused mainly by kick, leads to loss of valuable reserves and also causes property damage along with loss of life. Subsea blowout preventer(BOP) stack is the key equipment which ensures the safety of wellbore operation. Oncethe blowout occurs, the control system of BOP will actuate the corresponding valve and close the preventer within a specified time. This paper investigated the dynamic behavior of hydraulic control system of deep water subsea BOP stacks. Mathematic simulation models of the ram and annular preventers are established by using SimulationX software. Different cases are studied to verify whether it is appropriate to be operated according to API requirements at the water depth of 1524 m.Key words: Subsea BOP, Subsea drilling, Blowout preventer, Hydraulic control system, Simulation1. IntroductionRam preventer is a key part of the well control device. Its important implication for drilling, workover, oil control in the process of wellhead pressure, etc. When well with string, deserve to go up corresponding pipe ram to seal the annular space between casing and tubing string. When no string in well , deserve to go up the gate can be closed wellhead sealing ,when in emergency , the available shear damper cut tubing string in well, and closed wellhead. The deep water drilling BOP system plays a key role in oil and gas operation security ,protecting the marine environment and personal safety .At present, the development of deep water drilling BOP system in domestic is at the early stage , in order to improve the technical level of the key equipment in deep water drilling BOP system made in our country , the present technical status of the deep water BOP system used inmarine drilling riser at home and abroad are introduced at the beginning , the key equipment ofthe BOP stack and control units of deep water BOP system are researched especially. The main characteristics of the key equipment in deep water BOP system are analyzed, and their compositions and functions are illustrated. Finally, combined with domestic actual situations, the suggestions of research on deep water BOP system were given.Blowout in the oil and gas industry is a potential risk of human life injury, economic loss or environmental damage. There have been many reported incidents of blowouts in the past causing great damage to both human life and environment. A lot of money and hard work have been researching on how to prevent a blowout or constrain it with the minimum of damage.Blowout is caused mainly by kick. During the time of drilling the pressure of the formation should be kept under control. The formation pressure can be kept in control by using drilling fluids which should have a density more than that of formation fluids. If the density of formation fluids is higher than the density of drilling fluids, the formation fluidscan enter the borehole and circulate along with drilling fluids, which can pave the way for blowout 1.A subsea blowout preventer (BOP) system plays an extremely important role to provide safe working conditions for drilling activities in deep water regions. Subsea BOP failures could cause catastrophic accidents such as the explosion of the deep- sea petroleum drilling rig deep water horizon and the oil spill off the coast of Louisiana on April 20,2010.The subsea BOP on the deep water horizon rig was believed to have failedisolating the well before and after the explosions. The subsea BOP might have been faulty before the blowout, or it might have been damaged because of the accident 2.In the wake of recent disasters in oil and gas exploration and production, the performance evaluation of subsea BOP systems could be recognized.Relatively simple and economical hydraulic blowout preventer (BOP) control systems must be replaced by complex and expensive multiplex electric systems at depths where the hydraulic signal, traveling at the speed of sound, becomes too long for the function to be executed within the prescribed time period. In subsea applications, the total time to operate(close or open)a BOP can be split into two parts: signal time and fill- time. The signaltime is the up time required for the pilot signal from the surface to reach the corresponding valve in the subsea control pod. The fill- up time is the elapsed time between activation of the subsea pod valve and full execution of the BOP function.The purpose of this paper is to determine whether an electrohydraulic multiplex controls could be applied to water with depth of 1 524 m. Previous tests carried out by other companies have indicated that there was a strong possibility that a well-designed control system could perform as desired. API closing times are 45 s for rams and 60 s for annular BOP. The main task of this study is to build a mathematic simulation model for the BOP ram and annular functions and check if it is appropriate to be operated according to API requirements at the water depth of 1 524 m.The software that is used is Simulation X, which is an object-oriented program to analyze and optimize the dynamic behavior of fluid power components and systems. The built- in features of the hydraulic model elements include non-linear behavior of valves, mechanical and volumetric efficiency of actuators, complex friction and end stop models, and real gas and fluid behavior. Moreover, it provides a tailored subsea hydraulic library for subsea control applications. This allows for non-linear dynamic and flow behavior of the individual components in the analysis of the complete system interaction.2. System descriptionThe subsea BOP system mainly consists of the subsea BOP control system and the subsea BOP stack. A typical subsea BOP system is illustrated in Figure 1.The subsea BOP control system includes surface and subsea components. The surface components, located in the drilling rig, mainly consist of the central control unit (CCU).It is the kernel of the control system that provides full functional and pressure regulation capability. The CCU is micro processor-based, and typically utilizes triple modular redundancy (TMR) controllers to transmit commands from the surface to the subsea control pods. The subsea components of the control system are two completely independent control pods, the subsea blue pod and the subsea yellow pod, which afford redundant control of all subsea functions. Each pod includes subsea electronic module used to receive the command signals initiated on the surface.The configurations of subsea BOP stack vary because of the differences in drilling regions, ocean depths, and so on. Until now, no definite configuration standards have been established. As secondary barriers during drilling (the primary barrier is the drillingmud).BOP stack is designed to close the well annulus or the drill pipe. Two types ofpreventers, annular preventer and the ram preventer, are utilized. During deep water drilling, the BOP stack can be equipped with one or two annular preventers, although the BOP stack is usually equipped with four or more ram preventers. The different preventer configurations provide different levels of performances for the subsea BOP system.Specifically, a blind shear ram preventer is used to shear the pipe and seal the well, which is regarded as an emergency device. As shown in Figure.1, the typical subsea BOP stack is equipped with two annular preventers and four ram preventers, including a blind shear ram and three pipe rams.Figure 1. Typical architecture of a subsea BOP system3The subsea BOP stack is usually equipped with two hydraulic connectors, the LMRP connector and the well head connector. The LMRP connector is located in the middle of two annular preventers, which is used to connect the LMRP to the BOP stack. The well head connector is used to connect the BOP stack to the well head.The annular preventers, ram preventers, connectors, and other components such as the flexible joint, choke / kill valves, and choke / kill lines are in tegrated to form the whole subsea BOP stack.3. System model in SimulationXSimulationX contains a library of generic models for components and valves that are included in the most common deep water systems. Moreover, it provides lots of basic hydraulic and mechanical elements, which makes it easy to set up a tailored complicated model such as the subsea BOP stack system.3.1. Annular blowout preventerAn annular-type blowout preventer can close around the drill string, casing or anon-cylindrical object, such as the Kelly. Annular blowout preventers are also effective at maintaining a seal around the drill pipe even as it rotates during drilling.An annular blowout preventer uses the principle of a wedge to shut in the wellbore.Figure 2 shows the photo of an annular preventer. It has a donut-like rubber seal, known as an elastomeric packing unit, reinforced with steel ribs. The packing unit is situated in the BOP housing between the head and hydraulic piston. When the piston is actuated, its upward thrust forces the packing unit to constrict, sealing the annulus or open hole.Annular blowout preventer uses a “wedge-faced”(conical-faced)piston. As the piston rises,vertical movement of the packing unit is restricted by the head and the sloped face of the piston squeezes the packing unit inward, toward the center of the well bore. Forces acting on the piston during its actuation are shown in Figure 3.Where, q3 and q4 represent theworking pressure and the well pressure, respectively4.Figure 2.Annular blowout preventerFigure 3.Piston in annular preventer The elasticity of packing unit in annular preventer is estimated by using finite elementmethod. It is assumed that the last 3% of stroke is used to squeeze the packing unit around pipe. The estimated behavior of the annular element is shown in Figure 4.Figure 5 presents the model for an annular preventer. The model comprises elements from SimulationX library that are dedicated to hydraulics, in conjunction with the elements from the mechanical library. Annular preventer control pod is simplified into a hydraulic control system comprising of necessary elements including pressure regulator, directional valves and hose lines. Figure 4.Annular preventer compression forceFigure 5.Model for an annular preventer3.2. Ram blowout preventerA ram-type blowout preventer is similar in operation to a gate valve, uses a pair of opposing steel plungers, rams. The rams extend toward the center of the wellbore to restrictflow or retract open in order to permit flow. The inner and top faces of the rams are fitted with packers(elastomeric seals)that press against each other, against the wellbore, and around tubing running through the wellbore. Figure 6 shows a typical ram blowoutpreventer.Rams are of four common types such as pipe, blind, shear and blind shear. In addition to the standard ram functions, variable-bore pipe rams are frequently used as test rams in a modified blowout preventer device known as a stack test valve. Ram blowout preventers for use in deep water applications universally employ hydraulic actuation. Threaded shafts are often still incorporated into hydraulic ram preventers as lock rods that hold the ram in position after hydraulic actuation. By using a mechanical ram locking mechanism, constant hydraulic pressure need not be maintained. Other types of ram locks, such as wedge locks, are also used.Figure 6.Ram blowout preventerFigure 7. Piston in ram preventer Pressure exerting on the piston in ram preventer is shown in Figure 74.The model fora ram preventer is presented in Figure 8.Wedge lock is adopted in the model. The ram preventer control pod is also simplified into a hydraulic system comprising of necessary elements including pressure regulator, directional valves and hose lines.4. Simulation resultsFigure 8.Model for a ram preventerThe main task of this study is to understand the subsea hydraulic system behavior of BOP stacks under normal conditions and verify whether it is appropriate to be operated according to API requirements at the water depth of 1 524 m. The closing times of API are 45 seconds for ram preventer and 60 seconds for annular preventer.The evaluated system is similar to that used in Deep water Horizon. There are three hydraulic pumps at the water surface providing the required working pressure. The lengthof the rigid conduit line is 1 524 m with the outer diameter 88.9 mm. The total effective gas volume of LMP accumulators is 908 L and the pre-charge pressure is 27.6 M Pa.One important enquiry is to determine if the system capacity is capable to operate several actuator functions in series or parallel at the required water depth. Cases taking into account of different operation sequences of blowout preventers are simulated and the results with time plot are presented in details.4.1. Closing upper and lower annular preventers in seriesIn this case, upper annular preventer(UAP)is actuated to close when the time is 2 s. At the end of its actuation, lower annular preventer(LAP) st
收藏