1.1 本规程的目的是获取两相地热流体输送管道中存在的液体和蒸汽的代表性样本。 1.1.1 收集并妥善保存液体和蒸汽样品，以便在现场或场外分析实验室进行后续化学分析。 1.1.2 液体和蒸汽样品分析产生的化学成分数据可用于地热能勘探、开发和地热资源长期管理开发的许多重要应用。这些应用包括但不限于资源评估，如确定储层温度和储层流体的来源，基于示踪剂的生产流量和焓（TFT）测量，生产流体与暴露于流体中的生产、发电和回注硬件的兼容性（腐蚀性和结垢沉积潜力），长期- 现场开采期间的定期水库监测，以及包括排放测试在内的环境影响评估。 1.1.2.1 充分利用中所述应用中的化学成分数据 1.1.2 ，可能需要与两相流量、井筒和地热储层相关的具体物理数据。在许多应用中，对储层条件的流体化学（液体和蒸汽）进行数学重建是一项主要要求。至少，这需要精确了解样品点处的总流体焓和压力或温度。流体重建和对不同于样本采集点的条件的计算超出了本实践的范围。 1.2 这种做法仅限于从两个国家收集样本- 压力大于70 kPa表压（10 psig）且体积蒸汽分数至少为20的相流 %. 本规程不适用于单相流，例如压力高于闪点的泵送液体排放或过热蒸汽流。参考规范 E947 用于单相地热流体采样。 1.3 地热流体两相流（液体和蒸汽）的取样需要专用的取样设备和相对于两相流管线的适当方向的取样口。本规程适用于未配备单独生产分离器的油井。 1.4 这里描述的两相设备和技术通常是从单个生产地热井中获得代表性蒸汽和液体样本的唯一方法。 开发它们是为了解决常见的两相条件，例如: 1.4.1 生产流量不稳定，波动较大， 1.4.2 闪蒸至蒸汽或在生产系统中连续闪蒸的总流量百分比未知， 1.4.3 井筒、生产管道和取样装置中产出流体闪蒸期间和之后的矿物沉积， 1.4.4 管道内的流动分层和取样口处的异常流态，以及 1.4.5 闪蒸分数不足，无法获得蒸汽样品。 1.5 本规程涵盖了获得化学分析用代表性液体和蒸汽样品所需的样品位置、专用取样设备和程序。 1.6 本标准并非旨在解决与其使用相关的所有安全问题（如有）。本标准的用户有责任在使用前制定适当的安全、健康和环境实践，并确定监管限制的适用性。 有关具体的危险说明，请参阅第节 7. . 1.7 本国际标准是根据世界贸易组织技术性贸易壁垒（TBT）委员会发布的《关于制定国际标准、指南和建议的原则的决定》中确立的国际公认标准化原则制定的。 ====意义和用途====== 4.1 本规程的目的是获取样本点管道中存在的蒸汽和液相的代表性样本，而不允许蒸汽冷凝或分离器中出现额外液体闪蒸。 该实践的一个重要特点是使用旋风式分离器进行高效相分离，该分离器在足够高的流速下运行，以防止显著的热损失，同时保持与管道压力基本相同的内部压力。 4.2 该实践的另一个重要特点是将取样分离器定位在管道上的一个点上，在该点上，两相流至少部分分层，以帮助分离过程。没有必要也不可能通过采样分离器传递每个相的代表性比例以获得代表性样本。分离器通常连接到一个适当定向的端口，以收集每个特定相-通常在蒸汽管线的顶部和液体的底部。 在某些情况下，管道配置可能会产生不寻常的流态，而需要相反的流态。如果一个相与另一个相的比率不极端，则可以从管道侧面的水平端口获得每个相的代表性样本。 4.3 当必须从两相排放中收集液体或蒸汽样品或两者用于化学分析时，使用本规程。这通常包括当油井排放到大气中时的初始试井操作，或当油井排放到流体收集系统和发电厂时的常规油井生产。也可根据本规程对通过公共集输系统生产的多口井的组合两相流进行采样。 4.4 当个别油井向专用生产分离器生产时，通常不采用这种做法。在这些情况下，根据单相采样方法（规范）对生产分离器出口处分离的蒸汽和液体进行采样 E947 ). 然而，当分离器效率预计很低时，可在生产分离器的下游使用。在这些情况下，该方法用于从采集的样品中去除污染相。

1.1 The purpose of this practice is to obtain representative samples of liquid and steam as they exist in a pipeline transporting two-phase geothermal fluids. 1.1.1 The liquid and steam samples are collected and properly preserved for subsequent chemical analysis in the field or an off-site analytical laboratory. 1.1.2 The chemical composition data generated from the analysis of liquid and steam samples may be used for many applications important to geothermal energy exploration, development, and the long-term managed exploitation of geothermal resources. These applications include, but are not limited to, resource evaluations such as determining reservoir temperature and the origin of reservoir fluids, tracer-based measurements of production flow and enthalpy (TFT), compatibility of produced fluids with production, power generation and reinjection hardware exposed to the fluids (corrosivity and scale deposition potential), long-term reservoir monitoring during field exploitation, and environmental impact evaluations including emissions testing. 1.1.2.1 To fully utilize the chemical composition data in the applications stated in 1.1.2 , specific physical data related to the two-phase discharge, wellbore, and geothermal reservoir may be required. Mathematical reconstruction of the fluid chemistry (liquid and steam) to reservoir conditions is a primary requirement in many applications. At a minimum, this requires precise knowledge of the total fluid enthalpy and pressure or temperature at the sample point. Fluid reconstruction and computations to conditions different from the sample collection point are beyond the scope of this practice. 1.2 This practice is limited to the collection of samples from two-phase flow streams at pressures greater than 70 kPa gauge (10 psig) and having a volumetric vapor fraction of at least 20 %. This practice is not applicable to single-phase flow streams such as pumped liquid discharges at pressures above the flash point or superheated steam flows. Refer to Specification E947 for sampling single-phase geothermal fluids. 1.3 The sampling of geothermal fluid two-phase flow streams (liquid and steam) requires specialized sampling equipment and proper orientation of sample ports with respect to the two-phase flow line. This practice is applicable to wells not equipped with individual production separators. 1.4 The two-phase equipment and techniques described here are often the only way to obtain representative steam and liquid samples from individual producing geothermal wells. They have been developed to address common two-phase conditions such as: 1.4.1 Unstable production flow rates that have a large degree of surging, 1.4.2 Unknown percentage of total flow that is flashed to steam or is continuously flashing through the production system, 1.4.3 Mineral deposition during and after flashing of the produced fluid in wellbores, production piping, and sampling trains, 1.4.4 Stratification of flow inside the pipeline and unusual flow regimes at the sampling ports, and 1.4.5 Insufficient flash fraction to obtain a steam sample. 1.5 This practice covers the sample locations, specialized sampling equipment, and procedures needed to obtain representative liquid and steam samples for chemical analysis. 1.6 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use. For specific hazard statements, see Section 7 . 1.7 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee. ====== Significance And Use ====== 4.1 The objective of this practice is to obtain representative samples of the steam and liquid phases as they exist in the pipeline at the sample point, without allowing steam condensation or additional liquid flashing in the separator. A significant feature of the practice is the use of a cyclone-type separator for high-efficiency phase separation which is operated at flow rates high enough to prevent significant heat loss while maintaining an internal pressure essentially the same as the pipeline pressure. 4.2 Another significant feature of the practice is to locate the sampling separator at a point on the pipeline where the two-phase flow is at least partially stratified to aid in the separation process. It is neither necessary nor possible to pass representative proportions of each phase through the sampling separator to obtain representative samples. The separator is usually attached to an appropriately oriented port to collect each specific phase – normally on top of the line for steam and at the bottom for liquid. In some cases, piping configurations can generate unusual flow regimes where the reverse is required. If the ratio of one phase to another is not extreme, it may be possible to obtain representative samples of each phase from a horizontal port on the side of the pipeline. 4.3 This practice is used whenever liquid or steam samples, or both, must be collected from a two-phase discharge for chemical analysis. This typically includes initial well-testing operations when a well is discharged to the atmosphere or routine well production when a well discharges to a fluid gathering system and power plant. The combined two-phase flow of several wells producing through a common gathering system may also be sampled in accordance with this practice. 4.4 This practice is not typically employed when individual wells produce to dedicated production separators. In these cases, the separated steam and liquid at the outlet of the production separator is sampled in accordance with single-phase sampling methods (Specification E947 ). It may, however, be used downstream of production separators when separator efficiency is expected to be very poor. In these cases, the method is used to remove the contaminating phase from the samples being collected.