Table of Content

10 February 2022, Volume 44 Issue 1

Previous Issue   

ACADEMICIAN THOUGHTS

Research on the Mechanism and Countermeasures of Shaft Instability in the Southern Margin of Junggar Basin

SUN Jinsheng, LI Rui, WANG Ren, QU Yuanzhi, HUANG Hongjun

2022, 44(1):  1-12.  DOI: 10.11885/j.issn.1674-5086.2021.09.10.02

Asbtract ( 270 )   HTML ( 36)   PDF (40677KB) ( 295 )  

References | Related Articles | Metrics

Deep drilling in the southern margin of the Junggar Basin has problems such as high temperature and high pressure and instability of the borehole wall. The current oil-based drilling fluid technology is faced with huge challenges. According to the statistics of the complex situation of Well Hutan 1, based on the analysis of the fabric and characteristics of the rock samples of the unstable formation, the mechanism of the instability of the borehole wall is revealed. Combined with the technical requirements of deep drilling fluids in the southern margin, the self-developed nano plugging agent and super fine calcium carbonate and elastic graphite form a particle size gradation, constructing an oil-based drilling fluid system that can effectively seal the pores and fractures of the 0.05~50.00μm formation, the fluid loss of this system is only 2.8 mL after hot rolling at 180 ℃, and it is resistant to the 20% composite brine and 5% calcium sulfate pollution and can provide important technical support for deep drilling in the southern margin.

GEOLOGY EXPLORATION

Diagenetic Facies and Porosity Evolution of Tight Sandstone in Shahezi Formation

RAN Qingchang, ZHONG Anning, ZHOU Xiang, WANG Chao, YANG Dandan

2022, 44(1):  13-26.  DOI: 10.11885/j.issn.1674-5086.2019.11.12.02

Asbtract ( 188 )   HTML ( 9)   PDF (11252KB) ( 84 )  

References | Related Articles | Metrics

In order to make clear the characteristic and genesis of tight sandstone diagenetic facies in Shahezi Formation, the core, thin-section, SEM, physical properties and X-ray analysis have been combined and systematically studied in Xujiaweizi Fault Depression. The result is that there are five kinds of diagenetic facies such as muddy-filling diagenetic facies, feldspar-debris dissolution diagenetic facies, quartz overgrowth diagenetic facies, chlorite cementation diagenetic facies and carbon cementation diagenetic facies. The difference of mineral constituent and texture between different diagenesis facies which is controlled by sedimentation is the origin of porosity evolution, the type of main diagenesis and its intensity determine the porosity evolution path in different diagenetic facies and result in spatial differentiation of properties in macroscopic and pore structure in microscopic. Even though diagenesis destroy a lot of primary pore in feldspar-debris dissolution diagenetic facies in braided delta front and chlorite cementation diagenetic facies in fan delta front, they still retain a high property before gas injection in stage B of middle diagenesis phase, which make them a favorable reservoir for gas accumulation. The reservoir in muddy-filling diagenetic facies, carbon cementation diagenetic facies and quartz overgrowth have loss most of primary pore and complete the densification process before organic matters get matured, which make it difficult for gas injection and accumulation.

Controls of Multi-stage Tectonic Movement on Sandstones with Different Provenances

WANG Ai, ZHONG Dakang, WANG Wei, ZHOU Zhiheng, TANG Zicheng

2022, 44(1):  27-40.  DOI: 10.11885/j.issn.1674-5086.2020.01.09.03

Asbtract ( 137 )   HTML ( 4)   PDF (13830KB) ( 95 )  

References | Related Articles | Metrics

Based on ordinary thin sections and pore casting thin section observation, scanning electron microscopy, cathodoluminescence and X-ray diffraction analysis as well as mercury intrusion experiments, this thesis analysis the petrological characteristics, diagenesis, physical properties, pore types and pore evolution of the tight sandstone reservoirs of the Xujiahe Formation in the northeastern Sichuan Basin, furthermore studies the control effect of multi-stage tectonic movement on sandstones with different provenances. The results show that in the late Indosinian period, the difference in provenance supply and the type of parent rock of source area caused by the strength of the basin-forming orogenic activities in the study area resulted in different types of sandstone, which were described before, including the lithic sandstone of the Xu-2 tight sandstones, the calcarenaceous sandstone of the Xu-3 tight sandstones, the feldspathic lithic sandstone of the Xu-4 tight sandstones, and the quartz sandstone with lithic sandstone of the Xujiahe Formation in three area (western Yuanba Area, Bazhong Area, Malubei Area), respectively. Under the continuous influence of Yanshan Movement and Xishan Movement, Malubei strong deformation zone, Bazhong medium deformation zone and western Yuanba weak deformation zone are developed from near to far from the Daba Mountain foreland compressive zone. Different types of sandstones in different tectonic locations have experienced different diagenetic sequences and porosity evolution processes. The tectonic action controls the structural extrusion strength, and crack and fault development degree and scale, which further determines the preservation of the original pores and the later dissolution pores and the connectivity of the pores. It also controls the source-storage relationship and the degree of oil and gas charging, and ultimately controls natural gas yield.

A Study on the Cause of Tight Sandstone Reservoir Heterogeneity

ZOU Min, XIA Dongling, XIA Dongdong, PANG Wen

2022, 44(1):  41-52.  DOI: 10.11885/j.issn.1674-5086.2020.02.02.01

Asbtract ( 187 )   HTML ( 8)   PDF (13245KB) ( 115 )  

References | Related Articles | Metrics

Starting from the formation process of tight sandstone reservoir, the main method is to analyse reservoir differences reflected by kinds of test data, the genesis of tight reservoir heterogeneity in Chang 8 Member of Yanchang Section of Chuankou Strip in Honghe Oilfield in the south of Ordos Basin is studied. The superposition of sand bodies and the difference of debris particles caused by sedimentation have formed macro-heterogeneity, and the superposition of sand bodies has a great influence on the subsequent diagenesis and fracture development. The destructive diagenesis formed the basic pattern of reservoir heterogeneity; among them, compaction and calcareous cementation vertically form the characteristics of good physical properties of the middle part of the sand body and poor top and bottom; the overall difference of reservoir quality in the upstream and downstream formed by argillaceous cementation. In the late stage, the dissolution mainly developed in the middle of the sand body, which improved the quality of the reservoir locally and strengthened the heterogeneity of the reservoir. Fractures are mainly developed in thin sandbodies with different superposition patterns, which makes reservoir heterogeneity more complex. According to the drilling verification of Chuankou Strip in Honghe Oilfield, the geological factors at different stages have different effects on reservoir heterogeneity, forming the tight sandstone reservoir heterogeneity distribution.

An Analysis on the Characteristics of Deepwater Sandstone Reservior of Chang 6 Member, Yanchang Formation in Huangling Area

YANG Shasha, HUANG Xuri, JIA Jisheng, WU Zhixue, LI Weihua

2022, 44(1):  53-65.  DOI: 10.11885/j.issn.1674-5086.2020.02.22.01

Asbtract ( 144 )   HTML ( 6)   PDF (15191KB) ( 207 )  

References | Related Articles | Metrics

Taking the Chang 6 Member of the Yanchang Formation in Huangling Area of the Ordos Basin as the research object, the characteristics of the deep water sandstone of Chang 6 Member and the differences between different types of sand bodies are analyzed based on the abundant drilling and coring, logging and analysis of laboratory data. The results show that the reservoir rock types in the study area can be divided into three categories: sandy debris flow sand body, sandy slumping sand body and turbidite sand body according to their formation mechanism and structural characteristics. Among them, the content of quartz and feldspar and structural maturity in sandy debris flow sand body are relatively higher. The storage space is dominated by residual intergranular pores and feldspar dissolved pores. The physical properties of the reservoir are also significantly higher than those of the other two types of sand bodies. Further analysis found that due to the difference in structural maturity and mineral content, the compaction and dissolution of sandstone debris flow sand body is stronger in the early stage of diagenesis, and in the middle and late stages, soluble minerals increases pores and rupture increased fractures. It is determined that sandy debris flow sand bodies are the most favorable type of reservoir rock in the study area.

A New Method for Predicting Formation Dip Angle by Deep Mining Horizontal Well Data

GUO Jingmin, SUN Enhui, WANG Wei, LI Bo, YANG Dongdong

2022, 44(1):  66-78.  DOI: 10.11885/j.issn.1674-5086.2019.10.25.01

Asbtract ( 143 )   HTML ( 6)   PDF (2798KB) ( 102 )  

References | Related Articles | Metrics

According to the characteristics of more horizontal wells in offshore oilfield, the data of horizontal wells are deeply analyzed to predict the formation dip angle. According to the relative position between horizontal well and reservoir and the trajectory shape of horizontal section, the horizontal wells are classified into three types, namely "——" horizontal well, V-shaped horizontal well and low inclination horizontal well.This paper expounds the advantages and disadvantages of different types of horizontal wells in the process of data mining, and combined with the data characteristics of different types of horizontal wells, uses the methods of multi type resistivity logging cooperation, horizontal section splitting and comparison, true thickness direction correction and comparison to carry out secondary information mining, and predicts the formation dip angle.This method avoids the fact that the trajectory must be drilled out of the reservoir when the horizontal well predicts the formation dip angle, and obtains the regional structural change trend while ensuring the drilling rate. It can provide more geological basis for the fine development, adjustment and tapping potential of offshore oilfield.

A Study on Pattern and Mechanism of Surface Deformation of Underground Gas Storage in Hutubi

WANG Zegen, DOU Kepu, YANG Yinghui

2022, 44(1):  79-90.  DOI: 10.11885/j.issn.16745086.2019.11.22.03

Asbtract ( 174 )   HTML ( 6)   PDF (2178KB) ( 83 )  

References | Related Articles | Metrics

In order to explore the spatial distribution characteristics and influencing factors of the surface deformation of Hutubi underground gas storage by monitoring its surface deformation information. Using Sentinel-1A ascending orbit synthetic aperture radar data and based on small baseline subsets radar interferometry (SBAS-InSAR) technology, the time series surface deformation information of Hutubi underground gas storage during March 2017 to May 2019 is obtained. It turns out that in terms of time, from April to October every year, the surface of gas storage is about 10\begin{document}$\sim$\end{document}30 mm close to the line of sight of the satellite at the gas injection stage; at the same time, when the summer rainfall cannot meet the requirement of farmland water supply and groundwater needs to be pumped for irrigation, the gas storage area, especially the area close to farmland irrigation wells, has a obvious decrease in uplift phenomenon due to the pumping of groundwater during the gas injection period. During the gas production stage from November to March of the following year, the extraction of gas causes the surface of the gas storage to be 5\begin{document}$\sim$\end{document}10 mm away from the line of sight of the satellite. In space, the line of sight of the satellite on the west side of gas storage rises more than that on the east side, and the response of surface uplift is fast when gas is injected. At the same time, the area closer to the irrigation well will cause obvious decrease in uplift due to groundwater exploitation. It is found that the surface uplifted during gas injection and the surface subsided during gas production, and there is a tendency that decrease in surface uplift when the groundwater is extracted. The surface deformation in the gas storage area is the result of the combined effect of gas injection and groundwater extraction.

Stationary-phase Viscoelastic Prestack Time Migration for Rugged Topography and Its Application

MA Junmao, PAN Long, LI Jing, DING Guorong, SHI Xing

2022, 44(1):  91-99.  DOI: 10.11885/j.issn.1674-5086.2020.01.03.03

Asbtract ( 147 )   HTML ( 8)   PDF (11514KB) ( 38 )  

References | Related Articles | Metrics

Due to the absorption of the earth viscoelastic medium, the seismic wave propagates in the formation, which will cause the phase distortion of the wavelet and the attenuation of the high-frequency components. It cannot satisfy the requirements of the description of geological phenomena such as thin sand bodies, small faults and unconformity surfaces on the amplitude fidelity and resolution of seismic data. The stationary-phase viscoelastic prestack time migration method for rugged topography is based on the floating datum hypothesis. The method aims at compensating absorption attenuation along the propagation path of seismic wave. By introducing the equivalent \begin{document}$Q$\end{document} value, we propose the calculation method for dip gather of rugged topography, and control migration noise by the human-computer interaction picking up the Fresnel zone, realize the stationary-phase viscoelastic prestack time migration technical process for rugged topography, recover the high frequency components of the seismic wave attenuation, and achieves the purpose of improving the seismic imaging resolution. The obvious high-resolution processing results are obtained in the application of actual seismic data in the Junggar Basin.

OIL AND GAS ENGINEERING

An Experimental Study on the Distribution of Residual Oil by Water Flooding in Parallel Horizontal Well Pattern

LUO Xianbo, TANG Hong, ZHANG Zhang, YANG Junjie, ZHANG Jun

2022, 44(1):  100-112.  DOI: 10.11885/j.issn.1674-5086.2020.08.02.01

Asbtract ( 164 )   HTML ( 9)   PDF (1832KB) ( 120 )  

References | Related Articles | Metrics

The narrow development environment and high development cost of offshore oil fields have promoted the wide application of horizontal well development methods in water injection development in offshore oil fields. In view of the fact that most of the reservoirs in China's offshore oilfields are delta clastic deposits with strong reservoir heterogeneity, the current parallel horizontal well pattern water injection development is not good in effectiveness, and a large amount of remaining oil remains underground. The effects of displacement velocity and reservoir heterogeneity on the distribution of remaining oil from water flooding in parallel horizontal well pattern are studied by means of water flooding physical simulation experiment. The experimental results show that the degree of recovery in homogeneous reservoirs is higher than that in heterogeneous reservoirs, and the remaining oil is distributed near the toe of the production well. The change of displacement velocity will not affect the distribution of remaining oil in homogeneous reservoir. In the plane heterogeneous reservoirs with different permeability contrast, the higher the stage difference is, the later the water breakthrough occurs in the heterogeneous reservoir with lower permeability in the high permeability zone, and the ultimate recovery degree and average oil displacement efficiency are slightly higher than those with small permeability contrast and high permeability zone. The remaining oil is mainly located in the area near the heel-central part of the production well in the middle and low permeability zones. The remaining oil in the reservoirs with small grade difference and high permeability value in the high permeability zone is distributed in the area near the heel of the production well in the low permeability zone. The experimental study has concluded that parallel well pattern conditions are more suitable for lower displacement speeds and parallel horizontal well patterns are more suitable for heterogeneous reservoirs with larger grade differences and smaller maximum reservoir permeability, which provides theoretical and technical support for the design of horizontal well pattern in oilfield.

ASP Flooding Characteristics and Influencing Factors of Secondary Bottom Water Reservoirs

Lü Duanchuan, LIN Chengyan, LIN Chengyan, REN Lihua

2022, 44(1):  113-120.  DOI: 10.11885/j.issn.1674-5086.2020.06.01.01

Asbtract ( 170 )   HTML ( 5)   PDF (1226KB) ( 109 )  

References | Related Articles | Metrics

After long-term water-flooding extraction, primary integrated reservoir gradually evolves into secondary bottom water reservoir, and its remaining oil can be categorized as the weakly movable remaining oil in the upper-middle part, the by-passed movable remaining oil in the lower middle part, and the residual oil after water flooding in the high water flooded area. The tapping potential of such oil reservoir is exploited with ASP flooding. Based on the production data, the ASP flooding history is divided into three stages, namely the pre-effective stage, sustained effective stage, and the post-effective stage, and the time span of sustained effective stage is calculated. With quantified displacement characteristic curve, displacement capacities of wells in the sustained effective stage are calculated. Also, engineering, geographical, and chemical factors that affect the displacement effect are analyzed. The results show that the development characteristics of APS flooding in secondary bottom water reservoir differ considerably from those of conventional bottom water reservoirs, while the engineering and geographical factors have similar effects on these two reservoirs. The polymer components in oil displacement agents play an important part in oil-water seepage throughout the development history.

Application of Continuous Pack-off Technology in Packing-off Mudstone of Horizontal Well

LI Feng, LI Xiaoping, YANG Yong, LIU Chenglin, PEI Bailin

2022, 44(1):  121-131.  DOI: 10.11885/j.issn.1674-5086.2020.07.03.02

Asbtract ( 192 )   HTML ( 3)   PDF (6966KB) ( 53 )  

References | Related Articles | Metrics

In horizontal well drilling, mud blocking often occurs due to mudstone. The traditional packer is poor in function, and is restricked to specific condition. The laboratory physical simulation experimental materials for the application of continuous pack-off technology for anti-mud blocking are found during literature research. Though analyzing the feasibility of continuous pack-off technology for anti-mud blocking in production and factors influencing the application effect, the relative theory and computing method are proposed. The first application of continuous pack-off technology for anti-mud blocking is carried out, with an adjustment well in LF Oilfield as the first testing well. Since the well is on, the liquid productivity fluctuation is less than 4.8%. Comparing to the adjacent wells which did not drill through any mudstones, the fluid productivity index per meter is similar, only 2.02% difference to the average. All these evidences show that the technique has a great application effort on mud blocking prevention. It demonstrates that there are extensive application prospects for horizontal wells using continuous pack-off technology to prevent mud-blocking and keep efficient development.

Kinetics Modeling of Gas Hydrate Deposition and Blockage at Annular-mist Flow State in Production Wells of Deep Water Gas Fields

DONG Zhao, DIAO Yuqian, LI Zhong, JIANG Donglei, ZHANG Panfeng

2022, 44(1):  132-142.  DOI: 10.11885/j.issn.1674-5086.2020.05.20.01

Asbtract ( 157 )   HTML ( 4)   PDF (678KB) ( 176 )  

References | Related Articles | Metrics

During the production process of deep-water gas fields, gas hydrate can be formed in the wellbore near the wellhead at seabed, which can cause blockage of the production tubing. In this study, a gas-liquid two-phase annular-mist flow pattern is considered in the wellbore, and formation of hydrate particles in the gas core and the liquid films is assumed. A kinetics model for hydrate deposition and wellbore blockage is established, in which the formation, migration and wall adhesion of hydrate particles in the liquid film are considered, and the formation, coalescence, crushing and settling behaviors of hydrate particles are considered in the gas core. The model can be used to simulate and predict the hydrate blockage time and position in the wellbore under different operating conditions. The relative error between the model prediction results and the hydrate loop experiment blockage pressure drop is less than 10%. For a case study of a typical deep-water gas field, the risk analysis of wellbore hydrate formation and blockage is carried out, in which the growth rate of hydrate deposition layer in wellbore, its thickness distribution and complete blockage time are predicted.

Pipe String Integrity Evaluation and Water Injection Parameter Optimization for Injection Wells

MA Guorui, XU Honglin, ZHANG Zhi, YANG Kun

2022, 44(1):  143-150.  DOI: 10.11885/j.issn.1674-5086.2020.04.24.01

Asbtract ( 186 )   HTML ( 7)   PDF (972KB) ( 139 )  

References | Related Articles | Metrics

Aiming at the integrity failure of water injection string in Tahe Oilfield, based on the oxygen corrosion mechanism model and ECE model, the corrosion prediction model of water injection string has been established and its reliability verified. The influences of injection production stage and injection parameters on the corrosion rate of water injection string have been studied, and failure criterion has been established on the basis of tensile failure criterion. The charts of the limit allowable water injection volume for water injection wells under different injection displacement and dissolved oxygen concentration have been drawn. The results show that the corrosion of water injection well string mainly occurs during the water injection stage; with the increase of water injection displacement and dissolved oxygen concentration, the corrosion rate of the string increases, the allowable limit water injection amount decreases, and the dissolved oxygen concentration has a more significant impact on the corrosion of the string. It is suggested to strengthen the deoxidization and control the water injection displacement. The research results effectively guide the optimization of on-site water injection operation system, ensure the safety production of water injection wells, and improve the comprehensive benefits of water injection and oil increase.

Water Plugging Performance and Improvement of Preformed Particle Gel in Heterogenous Fractures

SUN Lin, ZHANG Yongchang, WU Yijun, XIN Jun, PU Wanfen

2022, 44(1):  151-157.  DOI: 10.11885/j.issn.1674-5086.2020.04.05.02

Asbtract ( 248 )   HTML ( 5)   PDF (6697KB) ( 143 )  

References | Related Articles | Metrics

Preformed particle gels (PPGs) have been widely used to control water production in high-temperature and high-salinity fractured reservoirs and their plugging effect is closely related to particle size and diversion. In this paper, carbonate outcrop cores with artificial fractures are used to simulate heterogeneous fracture reservoirs, and the water plugging evaluation and improvement experiments are carried out under the condition of 130 ℃ and 19.8\begin{document}$ \times $\end{document}10\begin{document}$ ^4 $\end{document} mg/L. The results show that the oversized PPGs or the excessive PPG-diversion in low-permeability fractures may aggravate the heterogeneity of fluid production, while the undersized PPGs are not suitable for the reservoirs with high water production strength. Therefore, we propose combining the curable resin-coated particles (CRPs) with PPGs to improve the water plugging performance. The CRPs form immobile packs in high-permeability fractures at reservoir temperature, which results in the larger breakthrough pressure gradients of the PPGs in high-permeability fractures relative to that of the PPGs in low-permeability fractures. The combined CRPs and PPGs can reverse the liquid-producing profiles of the heterogeneous fractures and eliminate the negative effects of improper PPG size and diversion rate on the water plugging. This study is helpful to further understand the water-plugging behaviors of PPGs in heterogeneous fractures and has positive significance for improving the water control effect in fractured reservoirs.

Research on Transient Flow Law of Multiphase Flow After Down-hole Blowout Preventer Setting

GU Lei, HU Yifan, MA Lanrong, YIN Huibo, LI Gao

2022, 44(1):  158-164.  DOI: 10.11885/j.issn.1674-5086.2020.05.20.03

Asbtract ( 146 )   HTML ( 7)   PDF (1041KB) ( 60 )  

References | Related Articles | Metrics

When drilling encounters high-pressure and high-production gas layers, there are many complicated situations such as lost circulation, gas invasion and overflow. At present, the research of wellhead BOP has become more mature, but research on the transient flow law of multiphase flow about the down-hole BOP is inadequate. For this reason, in view of the complex flow characteristics of the lower wellbore after setting of the down-hole BOP, a mathematical model and numerical solution of the formation-wellbore coupled transient flow after setting of the down-hole BOP are established. The pressure distribution and influencing factors are analyzed. The simulation results of the example show that, after setting of the down-hole BOP, the wellbore pressure evolution at different depths is basically the same; under different formation permeability, the bottom hole pressure increases exponentially and then increases linearly; as the amount of gas intrusion continues to increase, the initial down hole pressures will eventually stabilize around the formation pressure.

PETROLEUM MACHINERY AND OILFIELD CHEMISTRY

Research on Classification of Well Killing Method Based on Random Forest Fusion Model

ZHONG Yuan, ZHANG Tai, LI Ping, YANG Xuhua

2022, 44(1):  165-173.  DOI: 10.11885/j.issn.1674-5086.2020.05.12.02

Asbtract ( 1100 )   HTML ( 5)   PDF (589KB) ( 199 )  

References | Related Articles | Metrics

In wellhead pressure control operations, the traditional method relies too much on expert experience and the accuracy of mathematical model calculations. In this paper, we propose a multi-model fusion algorithm based on Random Forest (RF) for judgments of classification of well killing methods. Firstly, the structure and data of expert experience are transformed into a data form that can be used by machine learning models. Meanwhile, the basic data of oil and gas wells and working condition parameters are used as important parameters of intelligent model to describe the feature space of well killing operations. Then, the feature data are processed by feature engineering for feature selection, feature code and feature choose. Finally, a stacking double-layer fusion model based on Random Forest is constructed for the implement of predictions for classification of well killing method. The experimental results show that our method has more high prediction accuracy than other machine learning algorithms that has only single model.

Study on Test of Characteristics of A New Drum Pumping Unit

LIU Yongping, WU Long, WEI Yongqiao, DONG Changbin

2022, 44(1):  174-180.  DOI: 10.11885/j.issn.1674-5086.2019.11.09.01

Asbtract ( 1059 )   HTML ( 4)   PDF (1317KB) ( 108 )  

References | Related Articles | Metrics

In order to ensure the long stroke and low stroke motion characteristics of the pumping unit, improve the life and reliability of the commutation system, and to reduce operation noise, a new type of drum pumping unit is developed and a simulation loading test is performed. The test collects real time load and displacement signals in the ideal condition of rod pump oil extraction, and performs curve fitting processing on the collected experimental data to obtain the pump indicator diagram. Through analysis of pump power diagram, we make a study of the features of smoothness and impactlessness features of pump movement under different conditions by giving sucker rod weight load and motion frequency, and got a flattening pump power diagram. In this way, the optimal matching balance weight and stroke of the pumping unit are obtained, achieving stable pumping operation and energy saving. The accuracy of the method and the reliability of the pumping unit\begin{document}$ ' $\end{document}s drive reversing system and balance system are verified through the experiments, which provides new ideas of the type test of the simulated loading characteristics of the pumping unit, and has certain reference values.

A Study on the Determination of Hydrogen Sulfide in Natural Gas by Ultraviolet Absorption Method

DING Sijia, LIU Hong, YANG Yabing, CAI Li, XU Weifeng

2022, 44(1):  181-188.  DOI: 10.11885/j.issn.16745086.2020.05.15.01

Asbtract ( 1158 )   HTML ( 8)   PDF (2268KB) ( 106 )  

References | Related Articles | Metrics

Aiming at the problem for the ultraviolet absorption method in the determination of hydrogen sulfide content in natural gas, is still lack of national standards, a series of comparative tests of the instruments are carried out in different institutions, and data are processed according to Petroleum products–Determination of precision data in relation to methods of test(GB/T 6683-1997), requirements of the repeatability and reproducibility of UV absorption method for determination of hydrogen sulfide content are obtained, and the determination of the test results is made clear, which plays an important role in the preparation of the national standard of this method. At the same time, the comparative experiment with iodometric method is also used in the study. The results show that, compared with the artificial chemical titration method, the ultraviolet absorption method can control more influencing factors at a lower random level through the instrument, so it appears more stable and controllable. In addition, the continuous stability test data of 7 months show that stability of the test this method is excellent, and it has the long-term stability and accuracy requirements for online monitoring of hydrogen sulfide content in pipeline gas.