英语翻译要求：只求通顺,最好意思也通顺,纯粹软件翻译复制黏贴者勿扰Casing Design and Well Construction in Phase II Wells.One likely explanation for the casing pressure in the Phase II wells is the change in casing design a

英语翻译要求：只求通顺,最好意思也通顺,纯粹软件翻译复制黏贴者勿扰Casing Design and Well Construction in Phase II Wells.One likely explanation for the casing pressure in the Phase II wells is the change in casing design a
英语翻译
要求：只求通顺,最好意思也通顺,纯粹软件翻译复制黏贴者勿扰
Casing Design and Well Construction in Phase II Wells.
One likely explanation for the casing pressure in the Phase II wells is the change in casing design and unsuccessful cementing in the wells.
The typical Phase I casing design was to run a tieback to surface from the 7⅝” production liner and to partially cement within the 9⅝” casing (Fig.4 (a)).To accommodate a larger tubing size,no tieback was run in the Phase II wells (Fig.4(b)).Without the cement sheath,casing connections,which are usually weak links in the well design in terms of both pressure and mechanical integrity,are likely to control the integrity of the wells.Premature failures at connections result in entry points for high-pressure gas or water zones to communicate with the production casing.This was confirmed by downhole video logs run in wells C-7 and C-8 during operations to remediate sustained casing pressure.Gas entry was seen to occur in a connection just below the 9⅝” liner top packer in each well.The type of connection used in the Phase II wells is particularly weak in terms of pressure seal when subjected to external pressure.
Poor cement jobs in Phase II wells,as a result of lost returns during cementing,could also be largely responsible for the exacerbated loss of pressure seal integrity in
Phase II wells.
Well Life vs.Well Rate.Figure 7 plots the well life,together with the completion type and production rate for both Phase I and Phase II wells.The plot shows a surprisingly
consistent correlation between well life and peak production rate – well life drastically decreases with peak production rate increase.The Phase II wells,which had much higher production rates,have a significantly shorter well life (controlled by casing pressure).Wells C-6,635#1 and C-3,which had a lower peak rate compared to other Phase I wells,also had relatively longer well lives.Well C-6,which had the lowest peak rate throughout its production history,had the longest well life.This could be an indication that near wellbore behavior associated with high drawdown impacts both the formation/cement interface bonding and ultimate sand disintegration.Another possible explanation is the prematured loss of connection leak integrity due to the extra thermal stress resulted from the high producing rate.
Another surprising observation is that,compared to cased and perforated completions,the gravel pack completions in wells E-1 and 635#1 neither significantly increased production nor increased well life.Later fracpack completions did significantly increase production.
Casing Damage in the Overburden.The casing damagelocations from some of the Phase II wells,picked by various caliper logs,are also listed in Table 1.Out of the eleven casing damages observed,four are within 160 feet of a liner overlap (possible depth error is about 50 to 100 feet),five are within 200 feet of a known fault (the damage in Well D3 is close to both),and three are unrelated to any known non-uniform loading source.No damage can be correlated to the Siph (D) 110 or other sands.It seems that damage correlated to faults significantly increased compared to Phase I wells.This can be explained by the hypothesis that fault movement is activated or accelerated in the later field life when accumulated field compaction became significant,above 2.5% strain in this case.Fig.7 plots measured/estimated ID reduction with depth in Phase II wells.It shows a general tendency of restriction increase with time and depth.

英语翻译要求：只求通顺,最好意思也通顺,纯粹软件翻译复制黏贴者勿扰Casing Design and Well Construction in Phase II Wells.One likely explanation for the casing pressure in the Phase II wells is the change in casing design a
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套管井的设计与施工第二阶段韦尔斯.一个可能为在第二阶段油井套管压力的解释是,在外壳设计和失败的井固井变化.典型的第一阶段外壳设计,运行一个回接到地表7⅝“生产班轮部分水泥,并在9⅝”套管（图4（a））.为了适应规模较大的管道,没有回接是运行在第二阶段井（图4（b））.没有水泥环,套管连接,通常在设计和薄弱环节的压力和机械完整性方面,有可能控制井的完整性.早产儿在连接失败的切入点导致高压气体或水区,以沟通生产套管.这证实了井下视频日志运行在油井作业过程中ç - 7和C - 8补救持续套管压力.气体进入被视为发生在仅低于9⅝“班轮在每个井口封隔器的连接.在第二期水井使用的连接类型是特别薄弱的压力密封条件时受到外界的压力.普尔在第二阶段的工作井水泥作为一种收益损失在固井结果,也可以在很大程度上加剧了对损失负责压力密封完整阶段第二口井.幸福生活与井率.图7地块的良好生活,类型和完成为一期,产率以及二井.该图显示了一个令人惊讶的一致的相关关系以及生活和繁忙的生产速度-良好的生活与生产高峰急剧增加而降低速度.第二阶段井,该生产效率要高得多,有一个良好的生活大大缩短（由套管压力控制）.韦尔斯ç - 6,635＃1和C - 3,它有一个较低的失业率较高峰期水井等,也有相对较长的好生活.好ç - 6,在整个生产历史上最低的峰值速率,具有最长的幸福生活.这可能是一个迹象,近井高缩编的行为影响所产生的同时形成/水泥界面结合和最终解体的沙子.另一种可能的解释是完整的连接泄漏,由于额外的热应力的产生率高,导致prematured损失.另一项令人惊奇的看法是,相比套管和穿孔落成,在井砾石充填完井的E - 1和635＃1没有显着增加产量,也增加了好生活.后来fracpack落成并显着提高产量.问题补充：在覆套管损坏.从第二阶段的一些油井套管damagelocations,各卡尺日志回升,也列于表1.走出11套管损坏指出,在四个班轮160英尺的重叠（可能的深度误差约50至100英尺）,在200个已知故障英尺（维生素D3的井破坏的是接近两）,三是无关的任何已知的非均匀负载的来源.无损坏可与存在的Siph（四）110或其他砂.看来,损害相关,故障大幅增加相比,第一阶段的水井.这可以解释的是,断层运动激活或以后在外地生活领域加速时积累的假设成为重要的压实高于2.5％,在这case.Fig压力.7地块测量/估算的阶段深入编号减少二井.这显示了限制,总的趋势随时间和深度的增加.