scholarly journals Analysis of the application and impact of carbon dioxide media on the corrosion state of oil and gas facilities

2021 ◽  
Vol 250 ◽  
pp. 578-856
Author(s):  
Rafael Kantyukov ◽  
Dmitry Zapevalov ◽  
Ruslan Vagapov
Keyword(s):  
Carbon Dioxide ◽  
Oil And Gas ◽  
Carbonic Acid ◽  
Acid Corrosion ◽  
Co2 Storage ◽  
Hydrocarbon Production ◽  
Partial Pressures ◽  
Wide Range ◽  
Corrosion Of Steel ◽  
Corrosion State

Products of several currently operated production facilities (Bovanenkovskoye, Urengoyskoye oil and gas condensate fields, etc.) contain an increased amount of corrosive CO2. Effect of CO2 on the corrosion of steel infrastructure facilities is determined by the conditions of its use. Carbon dioxide has a potentially wide range of applications at oil and gas facilities for solving technological problems (during production, transportation, storage, etc.). Each of the aggregate states of CO2 (gas, liquid and supercritical) is used and affects the corrosion state of oil and gas facilities. Article analyzes the results of simulation tests and evaluates the corrosion effect of CO2 on typical steels (carbon, low-alloy and alloyed) used at field facilities. The main factors influencing the intensity of carbonic acid corrosion processes in the main conditions of hydrocarbon production with CO2, storage and its use for various technological purposes are revealed. Development of carbon dioxide corrosion is accompanied and characterized by the localization of corrosion and the formation of defects (pitting, pits, etc.). Even alloyed steels are not always resistant in the presence of moisture and increased partial pressures of CO2, especially in the presence of additional factors of corrosive influence (temperature, aggressive impurities in gas, etc.).

scholarly journals Media corrosiveness and materials resistance at presence of aggressive carbon dioxide

2021 ◽  
Vol 64 (11) ◽  
pp. 793-801
Author(s):  
R. R. Kantyukov ◽  
D. N. Zapevalov ◽  
R. K. Vagapov
Keyword(s):  
Carbon Dioxide ◽  
Oil And Gas ◽  
Gas Production ◽  
Carbon Dioxide Corrosion ◽  
Gas Field ◽  
Hydrocarbon Production ◽  
Field Development ◽  
Wide Range ◽  
Corrosive Effect ◽  
Equipment And Pipelines

At the present stage of gas field development, the products of many mining facilities have increased content of corrosive CO2 . The corrosive effect of CO2 on steel equipment and pipelines is determined by the conditions of its use. CO2 has a potentially wide range of usage at oil and gas facilities for solving technological problems (during production, transportation, storage, etc.). Simulation tests and analysis were carried out to assess the corrosion effect of CO2 on typical steels (carbon, low-alloy and alloyed) used at field facilities. Gas production facilities demonstrate several corrosion formation zones: lower part of the pipe (when moisture accumulates) and top of the pipe (in case of moisture condensation). The authors have analyzed the main factors influencing the intensity of carbon dioxide corrosion processes at hydrocarbon production with CO2 , its storage and use for various technological purposes. The main mechanism for development of carbon dioxide corrosion is presence/condensation of moisture, which triggers the corrosion process, including the formation of local defects (pits, etc.). X-ray diffraction was used for the analysis of corrosion products formed on the steel surface, which can have different protective characteristics depending on the phase state (amorphous or crystalline).

Carbonic Acid Corrosion of Steel

CORROSION ◽  
1975 ◽  
Vol 31 (5) ◽  
pp. 177-181 ◽  
Author(s):  
C. DE WAARD ◽  
D. E. MILLIAMS
Keyword(s):  
Carbonic Acid ◽  
Acid Corrosion ◽  
Corrosion Of Steel

Buffer systems in the rumen of sheep. I. pH and bicarbonate concentration in relationship to pCO2.

1955 ◽  
Vol 6 (1) ◽  
pp. 115 ◽  
Author(s):  
AW Turner ◽  
VE Hodgetts
Keyword(s):  
Carbon Dioxide ◽  
Carbonic Acid ◽  
High Pco2 ◽  
Bicarbonate Concentration ◽  
Bulk Fluid ◽  
Ruminal Fluid ◽  
Arterial Blood ◽  
Wide Range ◽  
The Relationship ◽  
Hasselbalch Equation

Experiments are described which emphasize the importance of avoiding loss of carbon dioxide when estimating the pH or bicarbonate concentration of ruminal fluid. The high pCO2 of ruminal fluid is stressed; this may be 10 times or more as great as that of arterial blood. The relationship between pCO2, pH, and [HCO3-] was examined in terms of the Henderson-Hasselbalch equation over a wide range of pCO2. From this, the pK1' of the carbonic acid system in four ruminal fluids was determined as 6.21-6.28, mean 6.25. The higher pH of saliva-free samples of ruminal fluid withdrawn by suction through a tube passed down the oesophagus, as compared with that of the bulk fluid obtained through a ruminal fistula, is considered to be due to loss of carbon dioxide during collection. A better estimate of intraruminal pH is obtained, even when salivary contamination occurs, if such samples are equilibrated with a sample of the animal's ruminal gas; if this is not practicable, an arbitrary gas mixture of high pCO2, e.g. 50 per cent. carbon dioxide and nitrogen, may be used.

scholarly journals PNEUMATIC FRACTURING PROBLEMS FOR HYDROCARBON FEEDSTOCK PRODUCTION INTENSIFICATION AT GAS CONDENSATE FIELDS IN UKRAINE

2021 ◽  
pp. 32-37
Author(s):  
Ivan Havrylovych Zezekalo ◽  
Hanna Anatoliyivna Dumenko
Keyword(s):  
Carbon Dioxide ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Inert Gases ◽  
Coal Seams ◽  
Gas Industry ◽  
Hydrocarbon Production ◽  
Current State ◽  
Develop Technology ◽  
Modern Technologies

The current state of the oil and gas industry of Ukraine and the possibility of increasing the hydrocarbon base due to the introduction of fields with compacted reservoirs, which contain significant gas resources. Some methods of intensification of wells that are used in Ukraine, such as hydraulic fracturing and the GasGun method, are considered. Their main shortcomings are given: unforeseen situations of depressurization of the water horizon, use of large volumes of water, utilization of process water, incomplete release of rupture fluid from the reservoir, swelling and hydration of clay components of the reservoir, impossibility of use at extremely high temperatures and pressures. The world modern technologies based on the action of inert gases in hydrocarbon production are covered. Studies on the application of anhydrous rock breaks and intensification methods using inert gases are analyzed. The application of the method of pneumatic compaction of coal seams in Ukraine with the use of flue gases for the release of methane and degassing of coal mines is presented. Modern studies on the use of liquid nitrogen and liquefied carbon dioxide as fracturing agents with rocks with low filtration–capacity properties are presented. The main advantages of using nitrogen, liquefied and supercritical carbon dioxide as reservoir decompression agents are presented. It is proposed to study the method of pneumatic compaction on different samples of rocks in the laboratory using various agents and surfactants, select the appropriate reagents and develop technology for pneumatic rupture of hydrocarbon reservoirs as a cheap and environmentally friendly alternative to existing methods.

scholarly journals GEOLOGICAL CONSIDERATION FOR CO2 STORAGE IN INDONESIA: A BASINAL SCALE OUTLOOK

2015 ◽  
Vol 1 (1) ◽  
Author(s):  
Hendra Amijaya
Keyword(s):  
Carbon Dioxide ◽  
Oil And Gas ◽  
Carbon Dioxide Capture ◽  
Co2 Storage ◽  
Geothermal Gradient ◽  
Gas Reservoirs ◽  
Coal Beds ◽  
North East ◽  
Geological Conditions ◽  
And Storage

Carbon dioxide capture and storage (CSS) is alternative of reducing atmospheric emissions of CO2. The concepts of CO2 storage refer to the injection of carbon dioxide in dense form into aquifers, which basically must meet several conditions. Three types of geological formations that can be used for the geological storage of CO2 are oil and gas reservoirs, deep saline formations and unmineable coal beds. Indonesia has 60 Tertiary basins, however that great precautions must be taken for selecting particular sedimentary basin in Indonesia for carbon dioxide storage because of high possibility of leakage and the need to find deep formations as CO2 host since the geothermal gradient is high. One possibility to find proper basins is by selected “mature” basin as the detailed geological conditions are well known. Candidates are are North East Java or South Sumatra Basins. Keywords: Carbon dioxide capture, storage, emission, basin.

The engineering challenges of CO2 storage

2018 ◽  
Vol 232 (1) ◽  
pp. 17-26 ◽  
Author(s):  
Frances C Harding ◽  
Alan T James ◽  
Hazel E Robertson
Keyword(s):  
Carbon Dioxide ◽  
Carbon Capture ◽  
Oil And Gas ◽  
Co2 Storage ◽  
Carbon Capture And Storage ◽  
Oil And Gas Industry ◽  
Industrial Plant ◽  
Carbon Dioxide Storage ◽  
Storage Site ◽  
Effective Manner

The permanent underground storage of large quantities of anthropogenic carbon dioxide from thermal energy and industrial plant is widely recognised as a fundamental tool which can help to avoid the worst impacts of climate change. To achieve this effectiveness, it will require widespread global deployment in a new industry which would rival the current oil and gas industry in its scale and ambition. Many of the technologies for carbon dioxide storage are the adaptations of oil and gas technology, but there are some important differences. These arise from:  1. the thermodynamic properties of carbon dioxide,  2. the essential requirement for long-term storage site integrity,  3. the absence of an established and mature business model for the industry and  4. the contrasting regulatory environments between carbon capture and storage and oil and gas extraction. Whilst the underground injection of carbon dioxide can truly be considered a proven technology, there are a range of engineering challenges to achieve this in a safe and cost effective manner. This paper sets out to explore some of these challenges and concludes with a view of what next steps are required to progress carbon dioxide storage effectively within the UK.  • The challenges of injecting carbon dioxide into offshore subsurface reservoirs:    ^ Arrival processing (heating before injection)    ^ Injectivity assessment – how many wells?    ^ Platform or subsea?    ^ Well design for long service operations and monitoring  • The challenges of forecasting reservoir and injection performance within porous and permeable storage reservoirs:    ^ Issues influencing carbon dioxide storage capacity    ^ Assuring storage site containment integrity    ^ Geology and engineering – uncertainty and risk  • Where has the industry got to and what are the practical next steps?

Different Flow Behaviors of Low-Pressure and High-Pressure Carbon Dioxide in Shales

SPE Journal ◽  
2018 ◽  
Vol 23 (04) ◽  
pp. 1452-1468 ◽  
Author(s):  
Bao Jia ◽  
Jyun-Syung Tsau ◽  
Reza Barati
Keyword(s):  
Carbon Dioxide ◽  
High Pressure ◽  
Storage Capacity ◽  
Co2 Storage ◽  
Low Pressure ◽  
Apparent Porosity ◽  
Apparent Permeability ◽  
Adsorbed Phase ◽  
Wide Range ◽  
Shale Reservoirs

Summary Understanding carbon dioxide (CO2) storage capacity and flow behavior in shale reservoirs is important for the performance of both CO2-related improved oil recovery (IOR) and enhanced gas recovery (EGR) and of carbon sequestration. However, the literature lacks sufficient experimental data and a deep understanding of CO2 permeability and storage capacity in shale reservoirs under a wide range of pressure. In this study, we aimed to fill this gap by investigating and comparing CO2-transport mechanisms in shale reservoirs under low- and high-pressure conditions. Nearly 40 pressure-pulse-transmission tests were performed with CO2, helium (He), and nitrogen (N2) for comparison. Tests were conducted under constant effective stress with multistage increased pore pressures (0 to 2,000 psi) and constant temperature. The gas-adsorption capacity for CO2 and N2 was measured in terms of both Gibbs and absolute adsorption. Afterward, the gas apparent permeability was calculated incorporating various flow mechanisms before the adsorption-free permeability was estimated to evaluate the adsorption contribution to the gas-transport efficiency. The results indicate that He permeability is the highest among the three types of gas, and the characteristic of CO2 petrophysical properties differs from the other two types of gas in shale reservoirs. CO2 apparent porosity and apparent permeability both decline sharply across the phase-change region. The adsorbed phase significantly increases the apparent porosity, which is directly measured from the pulse-decay experiment; it contributes positively to the low-pressure CO2 permeability but negatively to the high-pressure CO2 permeability.

scholarly journals Mathematical simulation of the rate of carbon dioxide corrosion at the facilities of Gazprom dobycha Urengoy LLC

2019 ◽  
Vol 121 ◽  
pp. 01019
Author(s):  
Aleksandr Yusupov
Keyword(s):  
Carbon Dioxide ◽  
Oil And Gas ◽  
Corrosion Damage ◽  
Gas Production ◽  
Special Role ◽  
Carbon Dioxide Corrosion ◽  
Oil And Gas Production ◽  
Working Medium ◽  
Wide Range ◽  
Equipment Wear

In Gazprom dobycha Urengoy LLC, as in other oil-and-gas production enterprises, there are problems of increased equipment wear due to corrosion. A special role there plays CO2 corrosion. Despite the homogeneity of the extracted fluid and even chemical composition of the working medium, the nature and intensity of corrosion damage to pipelines and equipment varies over a wide range, due to different thermobaric parameters of well operation. To determine parameters influencing the rate of corrosion most different methods of statistical analysis were used. The paper provides a methodology for compiling a mathematical model and assessing its reliability. As a result, the equation of carbon dioxide corrosion in relation to the conditions of Achimov deposits of Urengoy oil, gas and condensate field was obtained. The type of the obtained equation was chosen according to the model of the classical de Waard-Milliams carbon dioxide corrosion equation. The model proposed by the authors describes the processes of carbon dioxide corrosion more reliably than the de Waard-Milliams equation does. The disadvantage of the developed model is that it does not reliably describe the speed of corrosion in wells with corrosion rates, significantly exceeding the average values for all wells studied.

Sign in / Sign up

Export Citation Format

Share Document