气田增压生产后,天然气进脱水橇吸收塔的温度普遍升高,超过脱水橇吸收塔工艺运行温度.天然气进塔温度升高后影响天然气脱水效果(尤其是夏季6—8月),集气站天然气外输水露点控制难度大.文章讲述,为降低天然气进塔温度,依据前期项目建设调研结果,在增压集气站内压缩机组与脱水器之间增设固定板式换热器用于降低天然气进塔温度.2020年采气作业区X4增压站、X9增压站安装了固定板式换热器,通过对换热器运行情况及温度监测结果,定板式换热器能有效降低天然气进塔温度,保证脱水橇脱水效果,能够达到集气站外输天然气水露点的控制目的,固定板式换热器使用效果良好.

Since Majiagou-51+2 gas reservoir of Jingbian gas field has serious heterogeneity, it is significant to quantify, understand and appraise the heterogeneity for development layer adjustment and well infilling at middle or late stage of field development. Therefore, based on core analysis data, great amount of calculation and analysis on the variation coefficient, dart coefficient and deference of heterogeneity have been conducted for Majiagou-5 formations to make clearer the heterogeneity in and between layers.

Since Majiagou-51+2 gas reservoir of Jingbian gas field has serious heterogeneity, it is significant to quantify, understand and appraise the heterogeneity for development layer adjustment and well infilling at middle or late stage of field development. Therefore, based on core analysis data, great amount of calculation and analysis on the variation coefficient, dart coefficient and deference of heterogeneity have been conducted for Majiagou-5 formations to make clearer the heterogeneity in and between layers.

Accurate division of reservoir pressure system is an important basis for performance analysis, development appraisal, numerical simulation, production forecast and development adjustment. The Early Ordovician Majiagou-5 member reservoir of Jingbian gas field has characteristics of large area, thin layers, low permeability and serious heterogeneity, resulting in slow pressure recovery after shut-in, which led to difficulty in division of reservoir pressure system and formation pressure tracing. According to its geological characteristics, combination of building observation pattern, located pressure measurement and buildup test, etc. has been used. And reservoir development, fluid properties, inter-well interference, production performance and formation pressure distribution were all taken into consideration integrally. Therefore, pressure systems of Jingbian gas field were identified.

靖边气田马五1+2气藏非均质性强,定量化地描述其储层的非均质性、深入认识和评价储层的非均质性,这对科学指导气田开发中后期的层位调整和开发井加密调整具有积极意义.为此,以岩心物性分析资料为基础,采用统计方法对马五储层非均质性的变异系数、突进系数及级差等进行了大量计算分析,对储层层内及层间非均质性得出了全面而深入的认识.

储量是一个气田的物质基础,如何确定动储量及动储量的大小是气田开发中首先必须解决的问题.目前主要采用压降法确定动态地质储量.由于低渗透气藏渗流规律的特殊性,导致其压降储量曲线也表现出特殊规律.如果仍然按照普通气藏的处理方法计算低渗透气藏动态储量,会导致认识上的偏差及计算结果的失真.

Pressure is the essential factor to consider in gas field development. One of the key difficulties encountered in Jingbian Gasfield Development is how to obtain the accurate current formation pressure. On the one hand, since Jingbian Gasfield features low permeability, low abundance, large in area, thin reservoir, obvious heterogeneity and large production well interval (generally>2.5 km), it takes as long as several months to reach stability after pressure build-up upon re-startup. On the other hand, Jingbian Gasfield has been experiencing high daily gas yield in recent years and the chances to shut down well and measure pressure is rare. These factors attributed to the difficulty to measure current formation pressure. It presents a problem that has to be solved in developing low permeability gas reservoirs like Jingbian Gasfield, that is, how to achieve production target while still sustaining reservoir study with minimum monitoring activities. In line with geological characteristics of Jingbian Gasfield, based on continuous research and accumulation, the comprehensive technology has gradually been developed to measure current formation pressure, including building monitoring well network, setting up dedicated pressure monitoring well, well testing for pressure build-up on small scale and whole block shutdown for pressure measurement.

Jingbian Gasfield is a large gas field of low permeability and low abundance, encountering difficulty in its development due to special geological features. XX production zone is the key production block in Jingbian Gasfield, which dominates the production of the whole gas field to certain extent. Following continuous production in recent years, average wellhead tubing pressure of the production zone has dropped to 11Mpa and is still declining at the rate of about 1.8 MPa/year, which threatens sustainable constant-rate production. To tackle the problem, the whole XX production zone was shut-in for pressure survey during April to June in 2005 when recovery rate reached 17% and substantial shut-in pressure behavior data has been able to be obtained. Comprehensive analysis and study of the data has ascertained pressure variation status of the block, verified current productivity of a single well, determined pressure system classification, confirmed dynamic reserve of the block, which deepened our knowledge of the geology of the block.