Optimization of Hydrate Management in Deepwater Gas Well Testing Operations

2018 ◽  
Author(s):  
Shangfei Song ◽  
Bohui Shi ◽  
Weichao Yu ◽  
Wang Li ◽  
Jing Gong
Keyword(s):  
High Pressure ◽  
Low Temperature ◽  
Management Strategy ◽  
Oil And Gas ◽  
Management Strategies ◽  
Hydrate Formation ◽  
Optimal Dosage ◽  
Well Testing ◽  
Slurry Flow ◽  
Gas Well

Low temperature and high pressure conditions in deep water wells and sub-sea pipelines favour the formation of gas clathrate hydrates which is very undesirable during oil and gas industries operation. The management of hydrate formation and plugging risk is essential for the flow assurance in the oil and gas production. This study aims to show how the hydrate management in the deepwater gas well testing operations in the South China Sea can be optimized. As a result of the low temperature and the high pressure in the vertical 3860 meter-tubing, hydrate would form in the tubing during well testing operations. To prevent the formation or plugging of hydrate, three hydrate management strategies are investigated including thermodynamic inhibitor injection, hydrate slurry flow technology and thermodynamic inhibitor integrated with kinetic hydrate inhibitor. The first method, injecting considerable amount of thermodynamic inhibitor (Mono Ethylene Glycol, MEG) is also the most commonly used method to prevent hydrate formation. Thermodynamic hydrate inhibitor tracking is utilized to obtain the distribution of MEG along the pipeline. Optimal dosage of MEG is calculated through further analysis. The second method, hydrate slurry flow technology is applied to the gas well. Low dosage hydrate inhibitor of antiagglomerate is added into the flow system to prevent the aggregation of hydrate particles after hydrate formation. Pressure Drop Ratio (PDR) is defined to denote the hydrate blockage risk margin. The third method is a recently proposed hydrate risk management strategy which prevents the hydrate formation by addition of Poly-N-VinylCaprolactam (PVCap) as a kinetic hydrate inhibitor (KHI). The delayed effect of PVCap on the hydrate formation induction time ensures that hydrates do not form in the pipe. This method is effective in reducing the injection amount of inhibitor. The problems of the three hydrate management strategies which should be paid attention to in industrial application are analyzed. This work promotes the understanding of hydrate management strategy and provides guidance for hydrate management optimization in oil and gas industry.

Study on the Optimization of Hydrate Management Strategies in Deepwater Gas Well Testing Operations

2019 ◽  
Vol 142 (3) ◽  
Author(s):  
Shangfei Song ◽  
Bohui Shi ◽  
Weichao Yu ◽  
Lin Ding ◽  
Yang Liu ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Management Strategies ◽  
Hydrate Formation ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Optimal Dosage ◽  
Well Testing ◽  
Delayed Effect ◽  
Gas Well ◽  
Risk Margin

Abstract Low temperature and high pressure conditions favor the formation of gas clathrate hydrates which is undesirable during oil and gas industries operation. The management of hydrate formation and plugging risk is essential for the flow assurance in the oil and gas production. This study aims to show how hydrate management in the deepwater gas well testing operations in the South China Sea can be optimized. To prevent the plugging of hydrate, three hydrate management strategies are investigated. The first method, injecting thermodynamic hydrate inhibitor (THI) is the most commonly used method to prevent hydrate formation. THI tracking is utilized to obtain the distribution of mono ethylene glycol (MEG) along the pipeline. The optimal dosage of MEG is calculated through further analysis. The second method, hydrate slurry flow technology is applied to the gas well. Pressure drop ratio (PDR) is defined to denote the hydrate blockage risk margin. The third method is the kinetic hydrate inhibitor (KHI) injection. The delayed effect of KHI on the hydrate formation induction time ensures that hydrates do not form in the pipe. This method is effective in reducing the injection amount of inhibitor. The problems of the three hydrate management strategies which should be paid attention to in industrial application are analyzed. This work promotes the understanding of hydrate management strategies and provides guidance for hydrate management optimization in oil and gas industry.

Development and Application of a New Style Low Dosage Hydrate Inhibitors

2014 ◽  
Author(s):  
Weixin Pang ◽  
Qingping Li ◽  
Fujie Sun
Keyword(s):  
High Pressure ◽  
Low Temperature ◽  
South China Sea ◽  
Field Test ◽  
Oil And Gas ◽  
Hydrate Formation ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Effective Technology ◽  
Low Dosage

The hydrate is an important issue that the flow assurance has to face in the oil and gas industry, especially in the deepwater area. With high pressure and low temperature, the hydrate formation is easily happened and leads to plug in the pipeline. In addition to the traditional thermodynamic inhibitor, the low dosage hydrate inhibitors (LDHI) has been increasing used as a costly effective technology for gas hydrate control. The LDHI include kinetic hydrate inhibitor (KHI) and anti-agglomerant (AA), the former can inhibit the hydrate formation in the pipeline, and the latter can prevent the agglomeration and plug of hydrate particles. According to the properties of oil and gas of South China Sea, a new KHI and AA were developed, a field test of the KHI has been undertaken and the results indicate that it can prevent the hydrate formation and plug in the pipeline well, the lab evaluation of the developed AA is in progress and the field test will be performed by the next year.

Quantitatively Assessing Hydrate-Blockage Development During Deepwater-Gas-Well Testing

SPE Journal ◽  
2018 ◽  
Vol 23 (04) ◽  
pp. 1166-1183 ◽  
Author(s):  
Zhiyuan Wang ◽  
Yang Zhao ◽  
Jianbo Zhang ◽  
Xuerui Wang ◽  
Jing Yu ◽  
...  
Keyword(s):  
Water Depth ◽  
Gas Flow ◽  
Oil And Gas ◽  
Management Strategies ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Flow Assurance ◽  
Well Testing ◽  
Gas Well ◽  
Hydrate Layer

Summary Hydrate-associated problems pose a key concern to the oil and gas industry when moving toward deeper-offshore reservoir development. A better understanding of hydrate-blockage-development behavior can help flow-assurance engineers develop more-economical and environmentally friendly hydrate-management strategies for deepwater operations. In this work, a model is proposed to describe the hydrate-blockage-formation behavior in testing tubing during deepwater-gas-well testing. The reliability of the model is verified with drillstem-testing (DST) data. Case studies are performed with the proposed model. They indicate that hydrates form and deposit on the tubing walls, creating a continuously growing hydrate layer, which narrows the tubing, increases the pressure drop, and finally results in conduit blockage. The hydrate-layer thickness is nonuniform. At some places, the hydrate layer grows more quickly, and this is the high-blockage-risk region (HBRR). The HBRR is not located where the lowest ambient temperature is encountered, but rather at the position where maximum subcooling of the produced gas is presented. As an example case—a deepwater gas well with a water depth of 1565 m and a gas-production rate of 45 × 104 m3/d—the hydrate blockage first forms at the depth of 150 m. In the section with a depth from 50 to 350 m, hydrates deposit more rapidly and this is the HBRR. As the water depth increases and/or the gas-flow rate decreases, the HBRR becomes deeper. Inhibitors can delay the occurrence of hydrate blockage. The hydrate problems can be handled with a smaller amount of inhibitors during deepwater well-testing operations. This work provides new insights for engineers to develop a new-generation flow-assurance technique to handle hydrate-associated problems during deepwater operations.

Testing antifreeze protein from the longhorn beetle Rhagium mordax as a kinetic gas hydrate inhibitor using a high-pressure micro differential scanning calorimeter

2015 ◽  
Vol 93 (9) ◽  
pp. 1025-1030 ◽  
Author(s):  
Nagu Daraboina ◽  
Christine Malmos Perfeldt ◽  
Nicolas von Solms
Keyword(s):  
High Pressure ◽  
Differential Scanning Calorimeter ◽  
Oil And Gas ◽  
Hydrate Formation ◽  
Antifreeze Protein ◽  
Melting Behavior ◽  
Relative Strength ◽  
Operating Pressure ◽  
Longhorn Beetle ◽  
Low Dosage

Low dosage kinetic hydrate inhibitors are employed as alternatives to expensive thermodynamic inhibitors to manage the risk of hydrate formation inside oil and gas pipelines. These chemicals need to be tested at appropriate conditions in the laboratory before deployment in the field. A high pressure micro differential scanning calorimeter HP-μDSC VII (Setaram Inc.) containing two 50 cc high pressure cells (maximum operating pressure 40 MPa; temperature range –40 to 120 °C) was employed to observe methane hydrate formation and decomposition in the presence of hyperactive antifreeze protein from Rhagium mordax (RmAFP) and biodegradable synthetic kinetic inhibitor Luvicap Bio. A systematic capillary dispersion method was used, and this method enhanced the ability to detect the effect of various inhibitors on hydrate formation with small quantities. The presence of RmAFP and Luvicap Bio influence (inhibit) the hydrate formation phenomena significantly. Luvicap Bio (relative strength compared to buffer: 13.3 °C) is stronger than RmAFP (9.8 °C) as a nucleation inhibitor. However, the presence RmAFP not only delays hydrate nucleation but also reduces the amount of hydrate formed (20%–30%) after nucleation significantly. Unlike RmAFP, Luvicap Bio promoted the amount of hydrate formed after nucleation. The superior hydrate growth inhibition capability and predictable hydrate melting behavior compared to complex, heterogeneous hydrate melting with Luvicap Bio shows that RmAFP can be a potential natural green kinetic inhibitor for hydrate formation in pipelines.

Interfacial Evolution of Cement and Steel in CO2 Dissolved Solution Under High Temperature and High Pressure

2016 ◽  
Vol 35 (8) ◽  
pp. 821-826 ◽  
Author(s):  
Chengqiang Ren ◽  
Ye Peng ◽  
Bing Li ◽  
Shuliang Wang ◽  
Taihe Shi
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Oil And Gas ◽  
Chemical Change ◽  
Cylindrical Sample ◽  
Gas Well ◽  
Zonal Isolation ◽  
Well Cement ◽  
Interfacial Evolution

AbstractThe experiments were operated for the cylindrical sample (cement/steel) in high temperature and high pressure (HTHP) CO2 environment to simulate surrounding CO2 attack in oil and gas well. The interfacial evolutions between well cement and casing steel were measured, including mechanical property, structure alteration, chemical change and electrochemical character. The interfacial behaviors are attributed to the competition of hydration and degradation of Portland cement. The damage at the interface was faster than the cement bulk deterioration by carbonation. Thus, the interface provided a potential flow leakage pathway for the HTHP gas and fluid in the well, so improving interfacial stability between well cement and casing steel is the key issue to long-term zonal isolation.

scholarly journals Predictive Model to Evaluate Accommodation of Conflict Management Strategies and Board Performance of Oil and Gas Companies in Port Harcourt

2021 ◽  
Vol 4 (2) ◽  
Author(s):  
Eluozo S.N. ◽  
Ukpong, Uwem Johnson, ◽  
Eluozo . S.
Keyword(s):  
Conflict Management ◽  
Strategic Management ◽  
Management Strategy ◽  
Oil And Gas ◽  
Graphical Representation ◽  
Management Strategies ◽  
Exponential Phase ◽  
Lower Efficiency ◽  
Oil And Gas Companies ◽  
Oil And Gas Sector

This paper evaluates accommodation of conflict management strategies and board performances in oil and gas sector. The study detail the reflection of effectiveness, efficiency and productivity as the answer to thorough effectiveness in accommodation of conflict management in oil and gas sector, these parameters in the system express their efficacy on conflict management in these multinationals, this implies that for thorough efficiency, these variables must work simultaneously for effective and efficient in structural organization that can be a leading multinational sector in oil and gas environment. The study observed Linearized result from graphical representation explaining predominant lower efficiency and little higher efficiency in accommodation of conflict management in oil and gas companies. These experiences from the study monitor the system from generated simulation values that describe the growth rates in exponential phase of accommodation conflict strategic management. Despite exponential phase the results experienced lower parameters, when comparing on it variations showing its poor efficiency as observed in the study. Few periods observed higher effective accommodation on conflict strategic management. The developed model stimulation values were subjected to validation and both parameters generated favourable fits correlation, the study expressed the deficiency on accommodation of  conflict management strategy thus developed models that can monitor the fluctuation and progressive state of accommodation conflict  management strategy, it defines the reflection of other parameters that express the behaviour of the system in terms of conceptual approach to monitor these type of  strategic management in oil and gas companies.

scholarly journals Characterization of Physical Field and Flow Assurance Risk Analysis of Subsea Cage-Sleeve Throttling Valve

2021 ◽  
Vol 9 ◽  
Author(s):  
Donglei Jiang ◽  
Wenbo Meng ◽  
Yi Huang ◽  
Yi Yu ◽  
Youwei Zhou ◽  
...  
Keyword(s):  
Low Temperature ◽  
Production System ◽  
Oil And Gas ◽  
Negative Impact ◽  
Hydrate Formation ◽  
Simulation Method ◽  
Gas Production ◽  
Oil And Gas Development ◽  
Regular Production ◽  
Subsea Production System

The subsea production system is presently widely adopted in deepwater oil and gas development. The throttling valve is the key piece of equipment of the subsea production system, controlling the safety of oil and gas production. There are many valves with serious throttling effect in the subsea X-tree, so the hydrate formation risk is relatively high. In this work, a 3D cage-sleeve throttling valve model was established by the numerical simulation method. The temperature and pressure field of the subsea throttling valve was accurately characterized under different prefilling pressure, throttling valve opening degree, and fluid production. During the well startup period, the temperature of the subsea pipeline is low. If the pressure difference between the two ends of the pipeline is large, the throttling effect is obvious, and low temperature will lead to hydrate formation and affect the choice of throttling valve material. Based on the analysis of simulation results, this study recommends that the prefilling pressure of the subsea pipe is 7–8 MPa, which can effectively reduce the influence of the throttling effect so that the downstream temperature can be kept above 0°C. At the same time, in regular production, a suitable choke size is opened to match the production, preventing the serious throttling effect from a small choke size. According to the API temperature rating table, the negative impact of local low temperature caused by the throttling effect on the temperature resistance of the pipe was considered, and the appropriate subsea X-tree manifold material was selected to ensure production safety. The hydrate phase equilibrium curve is used to estimate the hydrate formation risk under thermodynamic conditions. Hydrate inhibitors are injected to ensure downstream flow safety.

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