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海洋天然气水合物开采方法及产量分析 总被引：2，自引：0，他引：2
海洋天然气水合物的巨大储量刺激了世界各国能源部门努力研究如何从天然气水合物储层生产天然气。根据水合物形成的条件，只有当水合物处在其相平衡条件以外，水合物才能分解。因此，水合物的开采方法只能为热熔法、抑制剂刺激法、减压法和地面分解法。为了对天然气水合物储层中气体的生产有个定量的评估，本文以水合物开采井为例，运用数学方法推导了水合物井中气体的产生量。结果表明，在天然气水合物储层中，天然气释放量是井内水合物分解温度、压力及水合物层气体渗透性的敏感函数。该函数可以用于天然气水合物井气体开采量的计算及对水合物储层可开采性评价。 相似文献
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开展储层参数和开采参数对天然气水合物开采产能影响的研究有助于其实际开采场址和开采方法的选择。以中国南海神狐海域SH7站位的地质参数为背景，采用TOUGH+HYDRATE软件系统地分析了储层压力、温度、孔隙度、水合物饱和度、渗透率、上覆层和下伏层渗透率等储层参数，以及降压幅度、降压井长度和出砂堵塞（通过改变井周网格渗透率反映出砂堵塞）等开采参数对天然气水合物降压开采产能的影响。数值模拟结果表明：(1)随着储层渗透率的增大，产气量有明显的增加；随着储层压力、孔隙度的增大以及上覆层和下伏层渗透率的减小，产气量有较大的增加；随着储层温度的增大，产气量有一定的增加；产气量随饱和度的增大先增大后减小。因此，实际开采时可优先选择渗透率大、上覆层和下伏层渗透率小、孔隙度大、温度较高、水合物饱和度适中的储层。(2)随着降压幅度的增大以及降压井长度增大，产气量有明显的增加；而随着出砂堵塞程度的加剧，产气量有非常明显的减少。因此，实际开采时可以通过增大降压幅度和降压井长度以及采取减轻出砂堵塞的措施来提高产气量。研究结果可以为我国将来天然气水合物开采区域及开采方式的选择和确定提供参考。 相似文献
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据日本经济产业省消息 ,开采天然气水合物的实验已获成功 ,并将在今后 1 0年开发实用技术 ,用于近海海底天然气水合物的开采。试验在加拿大西北部进行。一口深 1 2 0 0 m的井钻到天然气水合物层 ,通过井注入温水后 ,天然气水合物中的甲烷便溶在温水中 ,然后把溶有甲烷的温水抽回地面 ,进行分离得到甲烷。科学家预测 ,地球海底天然气水合物的蕴藏量约为 50 0亿亿立方米 ,相当目前世界年能源消费量的 2 0 0倍日本天然气水合物开采试验获得成功@蔡峰 相似文献
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《中国海洋大学学报(自然科学版)》2016,(10)
为了提高地震剖面上天然气水合物识别的可信度,以神狐海域天然气水合物钻探结果为基础,首次将剩余静校正处理技术应用于天然气水合物地震资料处理中。结果显示,在经过剩余静校正处理后的地震剖面上BSR特征清晰,反射能量强,极性反转明显。在此基础上,对比分析了过神狐海域2口水合物钻井的新老剖面品质,对比结果显示,不论是钻遇天然气水合物的SH3井,还是未钻遇天然气水合物的SH1井,经过剩余静校正处理后的新剖面成像精度得到了明显提高,剖面显示出的细微结构更加清晰,有利于天然气水合物的识别。因此,建议开展海域天然气水合物(尤其是扩散型水合物)的剩余静校正处理。 相似文献
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天然气水合物开采井孔出砂问题研究 总被引：1，自引：0，他引：1
《海洋地质与第四纪地质》2017,(5)
天然气水合物是一种重要的非常规能源,但水合物开采出砂问题成为制约其走向商业化开发的关键因素。南海北部陆坡是我国天然气水合物的重要赋存区,其水合物主要以分散状弱胶结方式赋存,研究其出砂问题显得极为迫切。研究表明储层出砂的根本原因是储层介质强度降低,而水合物储层介质强度受到水合物胶结模式、水合物饱和度、孔隙流体压力、流速及生产压差等影响。本文在对比分析天然气水合物储层出砂与常规油气藏出砂特征的基础上,总结了弱胶结疏松砂岩油藏出砂研究方法,为天然气水合物储层开采井孔出砂的研究提供思路和参考。 相似文献
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南海陆坡天然气水合物饱和度估计 总被引：5，自引：0，他引：5
基于双相介质理论和热弹性理论,建立了沉积层纵波速度与天然气水合物饱和度、弹性性质及地层孔隙度之间的关系。通过对比饱和水的理论P波速度与实际P波速度,可以得到天然气水合物饱和度。根据ODP184航次的电阻率、声波速度、密度等测井资料以及地质资料,初步推断南海陆坡存在天然气水合物。根据声波测井的纵波速度估算出南海1146和1148井天然气水合物饱和度分别为孔隙空间的25％～30％和10％～20％,1148井个别沉积层天然气水合物饱和度可达40％～50％。沉积层的纵波速度与饱和水速度差值越大,天然气水合物饱和度越高。 相似文献
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天然气水合物是一种赋存在海底沉积物孔隙中的清洁能源，含量巨大，具有很好的开发前景和研究价值。垂直井作为开采水合物的一种主要方式，在开采过程中，会改变天然气水合物沉积层的环境条件，随着开采井释放出大量的气体和水，在地层中形成超压，过高的孔隙压力会降低沉积物的胶结强度，破坏沉积层的稳定性，诱发海底滑坡。借助Flac3D软件建立高精度的海底斜坡模型，基于有限差分法对垂直多井动态开采水合物过程中的边坡稳定性进行了数值模拟，模拟了不同开采方案条件下采用多井开采，水合物分解量、开采井压变化等不同影响因素产生的地层力学响应和位移变化，基于安全系数法进对于水合物开采引起的边坡稳定性进行了初步分析。结果表明：多井开采条件下，随着水合物分解程度的不断增大，海底斜坡稳定性逐渐降低，当水合物分解程度达到80%时，安全系数会降低到1.0以下，边坡会失稳；随着井压的不断降低，海底斜坡稳定性同样逐渐降低，当开采井压降低到4 Mpa以下时，安全系数会降低到1.05以下，边坡变为欠稳定状态，存在发生海底滑坡的风险。 相似文献
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海底天然气水合物的开发利用对于国家能源安全与环境保护具有重要意义。然而,作为一种新型深海能源,海底天然气水合物至今仍未实现商业化生产。除开发技术等因素外,天然气水合物开发投入、产出的成本问题也是制约海底天然气水合物大规模开发的另一关键因素。文章从经济可行性的视角分析海底天然气水合物目前开采成本、未来开采成本的变化以及未来的价格优势,从而对天然气水合物开发的前景进行相关研究。研究结果显示,虽然目前天然气水合物的开采成本要高于常规天然气,但随着今后开采技术的改进,天然气水合物开采的总成本、边际成本和平均成本都会相应降低,当天然气水合物的价格低于常规天然气价格时,天然气水合物的商业化生产便可能实现。 相似文献
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Numerical studies of methane production from Class 1 gas hydrate accumulations enhanced with carbon dioxide injection 总被引：2，自引：0，他引：2
Class 1 gas hydrate accumulations are characterized by a permeable hydrate-bearing interval overlying a permeable interval with mobile gas, sandwiched between two impermeable intervals. Depressurization-induced dissociation is currently the favored technology for producing gas from Class 1 gas hydrate accumulations. The depressurization production technology requires heat transfer from the surrounding environment to sustain dissociation as the temperature drops toward the hydrate equilibrium point and leaves the reservoir void of gas hydrate. Production of gas hydrate accumulations by exchanging carbon dioxide with methane in the clathrate structure has been demonstrated in laboratory experiments and proposed as a field-scale technology. The carbon dioxide exchange technology has the potential for yielding higher production rates and mechanically stabilizing the reservoir by maintaining hydrate saturations. We used numerical simulation to investigate the advantages and disadvantages of using carbon dioxide injection to enhance the production of methane from Class 1 gas hydrate accumulations. Numerical simulations in this study were primarily concerned with the mechanisms and approaches of carbon dioxide injection to investigate whether methane production could be enhanced through this approach. To avoid excessive simulation execution times, a five-spot well pattern with a 500-m well spacing was approximated using a two-dimensional domain having well boundaries on the vertical sides and impermeable boundaries on the horizontal sides. Impermeable over- and under burden were included to account for heat transfer into the production interval. Simulation results indicate that low injection pressures can be used to reduce secondary hydrate formation and that direct contact of injected carbon dioxide with the methane hydrate present in the formation is limited due to bypass through the higher permeability gas zone. 相似文献
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天然气水合物广泛分布于陆地冻土带和深海地层,资源潜力巨大,其中Ⅱ类水合物藏占有重要地位。为加强对Ⅱ类水合物藏开采规律的认识,结合实际水合物藏参数,使用数值模拟方法研究了热水驱替开采Ⅱ类水合物藏的动态规律,并与降压法的开采效果进行了对比分析。结果表明:①热水驱替开采Ⅱ类水合物藏时,产气速率和分解气速率首先快速上升,然后以较快速度下降至趋于相对稳定;累产气和累分解气上升较快;气体采出程度和水合物分解程度均处于较高水平(>60%)。②热水驱替对Ⅱ类水合藏的开采具有一定的适应性,与降压法开采相比,热水驱替方式下储层水合物的分解更彻底,气体采出程度、水合物分解程度也更优,但具有较低的累积气水比,产水量较大。 相似文献
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According to the preliminary geological data of gas hydrate bearing-sediments (GHBS) at site GMGS3-W19 in the third Chinese expedition to drill gas hydrates in 2015, a production model using three different recovery pressures was established to assess the production feasibility from both production potential and geomechanical response. The simulation results show that for this special Class 1 deposit, it is a little hard for gas production rate to reach the commercial extraction rate because the degree of hydrate dissociation is limited due to the low reservoir permeability and the permeable burdens. However, the free gas accumulating in the lower part of the GHBS can significantly increase gas-to-water ratio. It also generates many secondary hydrates in the GHBS at the same time. Decreasing the well pressure can be beneficial to gas recovery, but the recovery increase is not obvious. In term of geomechanical response of the reservoir during the gas recovery, the permeable burdens are conducive to reduction of the sediment deformation, though they don't facilitate the gas recovery rate. In addition, significant stress concentration is observed in the upper and lower edges of GHBS around the borehole during depressurization because of high pressure gradient, and the greater the well pressure drop, the more obvious the phenomenon. Yield failures and sand production easily take place in the edges. Therefore, in order to achieve the purpose of safe, efficient and long-term gas production, a balance between the production pressure and reservoir stability should be reached at the hydrate site. The production pressure difference and sand production must be carefully controlled and the high stress concentration zones need strengthening or sand control treatment during gas production. Besides, the sensitivity analyses show that the hydrate saturation heterogeneity can affect the production potential and geomechanical response to some extent, especially the water extraction rate and the effective stress distribution and evolution. Increasing GHBS and its underlying free gas formation permeabilities can enhance the gas production potential, but it probably introduces geomechanical risks to gas recovery operations. 相似文献
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In 2006, the United States Geological Survey (USGS) completed a detailed analysis and interpretation of available 2-D and 3-D seismic data, along with seismic modeling and correlation with specially processed downhole well log data for identifying potential gas hydrate accumulations on the North Slope of Alaska. A methodology was developed for identifying sub-permafrost gas hydrate prospects within the gas hydrate stability zone in the Milne Point area. The study revealed a total of 14 gas hydrate prospects in this area.In order to validate the gas hydrate prospecting protocol of the USGS and to acquire critical reservoir data needed to develop a longer-term production testing program, a stratigraphic test well was drilled at the Mount Elbert prospect in the Milne Point area in early 2007. The drilling confirmed the presence of two prominent gas-hydrate-bearing units in the Mount Elbert prospect, and high quality well logs and core data were acquired. The post-drill results indicate pre-drill predictions of the reservoir thickness and the gas-hydrate saturations based on seismic and existing well data were 90% accurate for the upper unit (hydrate unit D) and 70% accurate for the lower unit (hydrate unit C), confirming the validity of the USGS approach to gas hydrate prospecting. The Mount Elbert prospect is the first gas hydrate accumulation on the North Slope of Alaska identified primarily on the basis of seismic attribute analysis and specially processed downhole log data. Post-drill well log data enabled a better constraint of the elastic model and the development of an improved approach to the gas hydrate prospecting using seismic attributes. 相似文献
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刘金龙 王淑红 AsiriObeysekara XIANGJiansheng PabloSalinas ChristopherPain JonnyRutqvist 颜文 《热带海洋学报》2020,39(1):94-105
海洋天然气水合物稳定带气烟囱结构中存在被水合物充填的裂隙, 表明在自然条件下沉积物中曾发生过流体压裂以及相关的流体流动和水合物形成。在水合物稳定带内实施人为的流体压裂工程, 并联合其他方法(如降压或注热)进行水合物开采, 有望提高开采效率。水合物稳定带内, 无论是自然条件下发生的流体压裂过程, 还是人为实施的流体压裂工程, 都存在水合物反应和沉积物裂隙变形之间的耦合响应。当前, 已有不少数值程序对水合物反应与沉积物弹塑性变形的耦合过程进行了定量研究, 但尚没有数值程序能够计算水合物反应和离散裂隙变形之间的耦合过程。文章将TOUGH+Hydrate程序、IC-FERST和Solidity两者的耦合程序进行了进一步耦合, 为水合物稳定带内的流体压裂计算提供了一种耦合计算方法, 同时通过一个算例初步验证了该耦合计算方法的可行性。验证结果表明, 该耦合计算方法经进一步改进后有望应用于定量研究水合物稳定带内的裂隙变形和水合物反应过程。 相似文献
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In 2006, the U.S. Geological Survey (USGS) completed detailed analysis and interpretation of available 2-D and 3-D seismic data and proposed a viable method for identifying sub-permafrost gas hydrate prospects within the gas hydrate stability zone in the Milne Point area of northern Alaska. To validate the predictions of the USGS and to acquire critical reservoir data needed to develop a long-term production testing program, a well was drilled at the Mount Elbert prospect in February, 2007. Numerous well log data and cores were acquired to estimate in-situ gas hydrate saturations and reservoir properties.Gas hydrate saturations were estimated from various well logs such as nuclear magnetic resonance (NMR), P- and S-wave velocity, and electrical resistivity logs along with pore-water salinity. Gas hydrate saturations from the NMR log agree well with those estimated from P- and S-wave velocity data. Because of the low salinity of the connate water and the low formation temperature, the resistivity of connate water is comparable to that of shale. Therefore, the effect of clay should be accounted for to accurately estimate gas hydrate saturations from the resistivity data. Two highly gas hydrate-saturated intervals are identified - an upper ∼43 ft zone with an average gas hydrate saturation of 54% and a lower ∼53 ft zone with an average gas hydrate saturation of 50%; both zones reach a maximum of about 75% saturation. 相似文献
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珠江口盆地神狐海域是天然气水合物钻探和试验开采的重点区域,大量钻探取心、测井与地震等综合分析表明不同站位水合物的饱和度、厚度与气源条件存在差异。本文利用天然气水合物调查及深水油气勘探所采集的测井和地震资料建立地质模型,利用PetroMod软件模拟地层的温度场、有机质成熟度、烃源岩生烃量、流体运移路径以及不同烃源岩影响下的水合物饱和度,结果表明:生物成因气分布在海底以下1500 m范围内的有机质未成熟地层,而热成因气分布在深度超过2300 m的成熟、过成熟地层。水合物稳定带内生烃量难以形成水合物,形成水合物气源主要来自于稳定带下方向上运移的生物与热成因气。模拟结果与测井结果对比分析表明,稳定带下部生物成因气能形成的水合物饱和度约为10%,在峡谷脊部的局部区域饱和度较高;相对高饱和度(>40%)水合物形成与文昌组、恩平组的热成因气沿断裂、气烟囱等流体运移通道幕式释放密切相关,W19井形成较高饱和度水合物的甲烷气体中热成因气占比达80%,W17井热成因气占比为73%,而SH2井主要以生物成因为主,因此,不同站位甲烷气体来源占比不同。 相似文献