Gas Facilities Research Articles

Determination of geochemical stability of swamp ecosystems of the taiga zone of Western Siberia to anthropogenic impact

Relevance. The need for scientifically based regulation of impacts on wetland ecosystems taking into account their specificity and geochemical stability. Aim. To determine the geochemical stability of wetlands in the taiga zone of Western Siberia to pollutants for two typical cases associated with: 1) operation of sludge pits; 2) discharge of domestic and industrial wastewater. Methods. Mathematical modeling, statistical methods. Results and conclusions. The authors have carried out the analysis of the results of studies of the chemical composition of wetland waters and extracts from peat and mineral soils of wetlands in the taiga zone of Western Siberia (mainly in the Tomsk region, as well as in the adjacent territories of the Khanty-Mansiysk Autonomous Okrug, Novosibirsk and Omsk regions). They obtained the estimates of the average values of geochemical indicators of wetland waters and peat by the depth of the peat deposit in peat bogs with varying degrees of anthropogenic impact. The paper introduces the method for assessing the anthropogenic impact of wastewater discharge and geomigration on swamps in areas where oil and gas facilities are located (permissible concentrations in wastewater entering swamp ecosystems), taking into account the «geochemical background» and sorption capacity of peat. In particular, the authors substantiated and tested the method for assessing the values of permissible concentrations, which should be considered as a «relatively safe» level of impact on swamp ecosystems, at which secondary pollution of swamp waters is not expected. It is shown that anthropogenic changes are mainly limited vertically by the upper layer of the peat deposit up to 1–2 m, and horizontally (within the active horizon of the peat deposit) – by areas up to 100–200 m.

Assessment of the influence of glycol and alcohol on the morphology and protective properties of iron carbonate in carbon dioxide corrosion of gas pipelines

The potential effect of hydrate formation inhibitors (glycols, alcohols) — components of the liquid phase of gas pipeline operating media — on carbon dioxide corrosion during the transport of aggressive gas has not been sufficiently studied. The paper presents the results of a study of the corrosive effect of glycol (alcohol) present in the liquid phase on the composition and properties of corrosion products on steel when modeling the main aggressive factors under conditions of transport of CO2-containing gas. On a corrosion stand, the aggressive conditions of alternating wetting of gas pipeline walls with water were reproduced. The fluid circulation characteristic of a partially filled pipeline can have an effect on preventing the formation or destruction of films of corrosion products (iron carbonate, siderite) on the steel surface. In places of cracking and peeling of siderite formed in the presence of CO2, conditions will be created for the formation of general and local corrosion damage. During simulation tests, monoethylene glycol and isopropanol, as well as their aqueous solutions of different concentrations, were used. For the first time, data on the formation and composition of non-stoichiometric siderite in water-glycol and water-alcohol media at CO2 partial pressures and temperature were obtained. By processing diffraction patterns obtained by X-ray diffraction, the degree of substitution of iron ions in non-stoichiometric siderites by other cations was determined. The dependence of the degree of substitution on the concentration of alcohol (glycol) in their aqueous solutions was analyzed. It was revealed that with an increase in glycol concentration, a decrease in the rate of local corrosion is observed. With a high glycol content, internal corrosion is completely suppressed in the presence of CO2. It has been established that in aqueous-alcoholic media at elevated temperatures, local carbon dioxide corrosion does not occur. This is apparently due to the uneven distribution of water and alcohol in the mixture. The results obtained can be used in assessing internal carbon dioxide corrosion in the presence of glycol (alcohol), used at gas facilities as an inhibitor of hydrate formation.

The Microbiologically Influenced Corrosion and Protection of Pipelines: A Detailed Review

Microbial corrosion is the deterioration of materials associated with microorganisms in environments, especially in oil- and gas-dominated sectors. It has been widely reported to cause great losses to industrial facilities such as drainage systems, sewage structures, food-processing equipment, and oil and gas facilities. Generally, bacteria, viruses, and other microorganisms are the most important microorganisms associated with microbial corrosion. The destructive nature of these microorganisms differs based on the kind of bacteria involved in the corrosion mechanism. Amongst the microorganisms related to microbial corrosion, sulfate-reducing bacteria (SRB) is reported to be the most common harmful bacteria. The detailed mechanistic explanations relating to the corrosion of pipelines by sulfate-reducing bacteria are discussed. The mechanism of microbial corrosion in pipelines showing the formation of pitting corrosion and cathodic depolarization is also reported. The current review provides theoretical information for the control and protection of pipelines caused by microbial corrosion and how new eco-friendly protection methods could be explored.

An integrated dynamic modeling workflow for acid gas and CO2 geologic storage screening in saline aquifers with faults: A case study in Western Canada

This study investigates the feasibility of storing the acid gas produced from the oil and gas facilities in Southern Saskatchewan into the Basal Sand aquifer using a coupled wellbore-aquifer-compositional reservoir model. The simulations investigate the pressure change around the fault in proximity of the primary storage location incorporating the influence of reservoir permeability, fault transmissibility, and wellbore configuration, on the factors critical to safe and efficient storage, such as plume migration, pressure changes, and CO2 storage capacity. A compositional fluid model created using an equation of state was integrated into the reservoir model. Simultaneous incorporation of fault transmissibility, phase solubility, water salinity, temporal in-situ hysteresis and structural trapping, and in-situ compositional tracking of individual gas components is considered as the main novelty of this work. The main challenge of the study was the lack of available data to characterize the aquifer. To this end, a comprehensive workflow of reservoir studies and modeling was applied to reduce the uncertainties and evaluate the site selection. The Basal sand scoping models reveal that the aquifer is expected to handle the required disposal volume given its extent. The injected acid gas plume migrates laterally and preferentially towards the northwest, away from the fault, owing to the aquifer's geological structure. CO2 remains entirely in the supercritical state, offering storage advantages due to its lower volume. The reservoir permeability significantly impacts the pressure patterns with lower permeability formations triggering higher wellhead injection pressures. Substantial pressure increases around the sealing fault can be observed. Pressure changes of 110 kPa (16 psi) to over 400 kPa (58 psi) were observed at the fault segment after 20 years of continuous gas injection for the expected range of reservoir properties. Mitigation strategies to minimize the increase in fault pressure entail relocating the injection site away from the fault or utilizing a horizontal well trajectory and using an observation well near the fault for monitoring any pressure buildup and slippage.

Detection of Methane Leaks via a Drone-Based System for Sustainable Landfills and Oil and Gas Facilities: Effect of Different Variables on the Background-Noise Measurement

In recent years, thanks to the great diffusion of drone technology and the development of miniaturized sensors that can be connected to drones, in order to increase the sustainability of landfills and oil and gas facilities, interest in finding methane leaks and quantifying the relative flow has grown significantly. This operation requires the methane background concentration to be subtracted from the calculations. Therefore, in order to proceed with a right estimate of CH4 flows emitted, the possibility of correctly measuring or estimating the background level becomes crucial. The present work intends to illustrate the effects of different variables on the background-noise measurement in a drone-based system that uses a tunable diode laser absorption spectrometer (TDLAS). The methodology used is that of field testing; the data acquisition campaign consisted of the execution of 80 flights during which different flight variables (drone speed, flight altitude) were tested; the flights were repeated in different weather and climate conditions both during the same day and in different periods of the year. Different surfaces, similar to those found in landfill or natural gas sites, were also tested. In some of the field trials, a controlled methane release test was performed in order to verify how much the quantification of the methane flow can vary depending on the background level used. The results of the different field trials highlighted the best conditions under which to measure methane emissions with a TDLAS sensor in order to minimize the number of outliers: flight altitude not exceeding 15 m above ground level; the drone speed appears to have less impact on the results, however, it is optimal between 1 and 2 ms−1; a very sunny day produces much higher methane background levels than a cloudy one. The type of surface also significantly affects the measurement of background noise. Finally, tests conducted with a controlled methane release highlighted that different levels of background have a significant impact on the estimation of the methane flux emitted.

FalconScan: A hybrid UAV-crawler system for NDT inspection of elevated pipes in industrial plants

Periodic non-destructive testing (NDT) of pipes and tanks is vital in industrial plants, such as Oil & Gas facilities, to proactively detect defects and corrosion before leaks and forced shutdowns occur. This paper presents a hybrid system, consisting of a UAV and a crawler, which enables detailed contact-based inspection of elevated pipes, in pursuit of eliminating the need for dangerous scaffolding and manual inspection to improve safety and reduce cost. Similar to avian animals, the UAV autonomously perches on the pipe to conserve energy. A small inspection crawling robot is carried by the UAV, and is subsequently released onto the pipe’s surface to inspect its health. The crawler uses magnetic wheels for agile mobility and houses an ultrasonic testing (UT) sensor to thoroughly scan the pipe and detect wall thinning, which is a precursor for leaks. Finally, the crawler re-docks with the UAV, which in turn detaches from the pipe to fly back home or inspect another pipe. The multi-robot system is designed for and tested on pipe diameters as small as 8 in.

Multi-Criteria Decision Analysis for Sustainable Oil and Gas Infrastructure Decommissioning: A Systematic Review of Criteria Involved in the Process

The decommissioning of oil and gas (O&G, hereafter) facilities presents complex challenges when addressing the diverse needs of stakeholders. By synthesizing information from previous Multi-Criteria Decision Analysis (MCDA, hereafter) studies on decommissioning projects, this study aims to do the following: (a) formulate a structured set of criteria adaptable to MCDA for both offshore and onshore O&G decommissioning, (b) identify and analyze the evolving trends and regional disparities in MCDA for decommissioning, and (c) explore current O&G onshore decommissioning procedures and map specific criteria to these processes. Following a systematic literature review approach, this study analyzed 63 references across four stages from 2006 to 2024 and identified 158 criteria. These criteria were consolidated into a framework of 22 factors across dimensions comprising technical, environmental, societal, financial, health and safety considerations, and additional concerns from stakeholders. This study observed a significant focus shift from technical aspects to environmental considerations in decommissioning practices from 2011 onwards, reflecting growing awareness of sustainability. It also revealed regional differences, such as the technical emphasis in the North Sea and environmental concerns in Australia. Furthermore, this study refined O&G onshore decommissioning procedures and identified criteria gaps for further research, particularly in societal impact regarding public resource availability, recreational opportunities, and operating company reputation. The study provides a robust foundation for the development of future MCDA frameworks tailored to O&G infrastructure decommissioning projects, thus supporting long-term environmental and social sustainability.

Analysis of Safety of Offshore Oil and Gas Facilities

Analysis of Safety of Offshore Oil and Gas Facilities

Causes of Safety Barrier Failures at Oil and Gas Facilities in Nigeria: A Technical Approach

This study investigates the company-controlled causes of barrier failure in Niger Delta region of Nigeria. Also, it focuses on oil and gas facilities and their operations involving hydrocarbon handling. Safety Barriers in the oil and gas industry are crucial safety systems designed to prevent hazards and mitigate the consequences of incidents. These barriers, encompassing technical, operational, and organizational elements, play a significant role in handling hazardous substances and preventing their unintended release. Despite their importance, barrier failures have been identified as major causes of process safety incidents globally, including Niger Delta region of Nigeria. A cross-sectional research design, using a questionnaire to collect primary data from 132 personnel across 12 facilities, was employed. Statistical data analyses were carried out using XLSTAT Version 2016. Findings indicate that process upsets and technical/physical failures are significant risk influencing factors, while human and operational errors, though present, are less impactful. Key technical failures include degradation of valve sealing and flange gaskets, while process upsets often result from overpressure and malfunctioning transmitters. The study highlights the need for improved risk reduction strategies and periodic training to enhance safety practices in the Niger Delta's oil and gas industry. Recommendations include increasing technical components of risk strategies and ensuring regular maintenance and compliance with safety regulations; that is, proactive maintenance strategies to mitigate the identified risks.

Evaluation Analysis of Small Capacity Rooftop Solar Electricity (PLTS) Development Plans at PT Pertamina Gas

Solar Power Plant (PLTS) is one type of new and renewable energy (EBT) generated from the Sun. Indonesia is a country that has considerable solar energy development potential of 4.8 Kw h/m2, but currently its utilization is still very low at only 0.01%. This study aims to evaluate the development plan of small-capacity rooftop solar power plants at oil and gas facilities owned by PT Pertamina Gas (Pertagas). This study uses PVSyst and Helioscope software to analyze the potential and efficiency of rooftop solar power plants. The results show that the planned installation of small-capacity rooftop solar power plants (±0.15 kW) in several Pertagas operational areas can support electricity supply for oil and gas distribution in Indonesia. The utilization of solar energy, which is one of the new renewable energy (EBT), is expected to increase the national energy mix in accordance with the government's target. This research provides evaluation and recommendations for the development of rooftop solar power plants at oil and gas facilities to support national energy independence and security.

Assessment of Initial Seismicity for Offshore Platforms on the Example of the Pechora Sea

Seismotectonic and seismoacoustic studies carried out during the expedition onboard the R/V ʺAkademik Boris Petrovʺ in the Pechora Sea revealed a paleoseismodislocation confined to a fault zone tracing the Severoural seismic lineament. The amplitude of this dislocation (the relative displacement of its sides) makes it possible to estimate the magnitude of the ancient earthquake that occurred within the Severoural lineament. Using the value of this magnitude, estimates were made of the maximum seismic impacts on offshore oil and gas facilities that are already in operation and are being designed for construction in the northeastern part of the Pechora Sea. These assessments of essential images differ in a big way from similar assessments made earlier. The method of searching for paleoseismic dislocations using seismoacoustic methods, as well as lineament analysis, can be used to assess the initial seismic impacts in water areas.

ECONOMIC, ORGANIZATIONAL AND TECHNICAL PROBLEMS OF OIL AND GAS FIELD ABANDONMENT

More and more mature fields in the old oil-producing regions are now in the stages of declining production, and their operation is close to completion, therefore, the upcoming liquidation work is of particular relevance and importance. Decommissioning of developed or inactive oil and gas wells is associated with a number of environmental, economic and legal problems. Liquidation of oil and gas facilities can become a significant expense for companies, especially if the budget deficit does not fully pay off during operation. At the same time, the negative impact of field development on the environment is not limited to the period of active production. With the onset of liquidation work, subsoil users may have obligations to government agencies in the form of taxes, licenses and other payments, which also increases their financial burden. Interaction between the state and subsoil users in the process of development and decommissioning of oil and gas fields becomes an important factor in the rational use of natural resources. Often, control over the liquidation of abandoned or decommissioned fields is entrusted to the state, although companies also have obligations to report on planned and implemented related activities. Since liquidation measures are a rather labor-intensive process that requires careful planning and financial resources, subsoil users sometimes evade responsibility, citing the lack of the necessary amount of financial resources to carry out these works. The article provides an overview of international experience in approaches to financing liquidation work. Mechanisms of legal regulation of relations between state management bodies and subsoil users, organizational, technical and economic problems of liquidation of oil and gas fields, as well as a number of approaches to effective financial support for the decommissioning of oil and gas facilities are considered. In conclusion, based on the presented analysis of the problems of the industry and international experience in organizing liquidation measures, the authors give several of their proposals, the implementation of which can be considered necessary preparatory work for effectively solving the problems of eliminating the consequences of the operation of hydrocarbon deposits with the onset of the desired economic stability.

Utilising InSAR for monitoring infrastructure at national scales

Interferometric SAR (InSAR) is now a widely used tool for the monitoring of infrastructure, in particular mines, dams, and oil and gas facilities. The technology is also widely used for the monitoring of construction activities such as tunnelling. With the growth of globally available and continuously updated SAR datasets, the monitoring of entire regional and national infrastructure networks is now feasible. Here we show how continuously updated, network-wide, InSAR datasets can be used to proactively manage large infrastructure networks such as roads, railways, and water pipelines. In the UK continuously updated InSAR data (derived from Sentinel-1 SAR data) is being effectively used across the entire railway network to proactively monitor potential embankment failures, large-scale landslides, and potential hazards outside of the boundary fence. A challenge of using InSAR data in this way is the huge volume of data that is available, as such custom risk metrics and machine learning algorithms are applied to highlight some of the areas at heightened risk. InSAR is also being applied to tackle the issue of water pipe leakage caused by natural ground movements, such as soil shrink-swell. In this case, regularly updated InSAR data has been used in the UK and Australia to detect areas at elevated risk of pipeline failures based on ground movement patterns, and by combining historical movement data and known failure events it is possible to refine such models. With expanding global SAR constellations proactive, nationwide, monitoring of critical assets is now possible, with the challenge being how we derive insight from these very large datasets.

Survey of Radiological Parameters at a Dumpsite Near an Oil and Gas Facility in Bayelsa State, Nigeria

The issue of proper waste management is becoming more critical with the increase of civilization and urbanization. Waste generation and disposal could increase levels of human radiation exposure. The dose rates from possible radioactive materials at Gbaraun-toru dumpsite have been investigated. Radiation survey meter was used to assess the dose rates at the site. Model equations were also used to estimate the health-related radiological parameters for the flux of scavengers and individuals using the dump site. The values of the measured dose rates at the dumpsites lie between (0.01 – 0.016) mRh-1 with a mean of 0.013 mRh-1. Absorbed dose rates and equivalent dose rates estimated ranged from (87.4 – 139.4) with a mean of 116.2 and (0876 – 1.402) with a mean of 1.113 . Annual effective dose rates, organ doses, and the excessive lifetime risk of cancer ranged from (0.357– 0.572) with mean 0.454 mSvy-1, (0.139 – 0.248) and (0.94 – 1.54) × 10-6 with mean of 1.28 × 10-6 respectively. Conclusively, the estimated absorbed measured rates for the study are above the safe limit (54 nGyh-1), while, others are within the safe limit (1 mSvh-1). This suggests that there may be an increment in the level of exposure of the workers at the dump sites, hence, regular radiological studies should be carried out in the study area

Probabilistic evaluation of the permeability of the rocks of the elementary cell of a geological model

The article proposes a new method for calculating the permeability of a geological model cell using probabilistic methods. It is proposed as an alternative to the generally accepted method, which is based on the use of empirical dependencies between porosity and permeability based on the results of laboratory core tests. The proposed method allows us to calculate the dependences of the probabilities of exceeding certain permeability values on porosity. These are of interest for studying the geological structure of oil and gas facilities in the process of their modeling. In this work, the boundary values of filtration properties corresponding to the boundaries of reservoir classes in the classification proposed by A. A. Khanin in 1969 were used. The article discusses the problems arising from the integration of different-scale levels. One of their solutions can be obtained by using the Monte Carlo method. In particular, its use helped to simulate the reservoir properties of rocks in a virtual cell of a geological model based on analyses of the results of previous studies of core samples in laboratory conditions. The approximation of the probabilities of exceeding the corresponding values of permeability from porosity allows us to calculate histograms of this parameter for each cell of the model. To do this, it is necessary to determine the differences in the probability functions that are used for neighboring permeability thresholds. In turn, this makes it possible to perform a differentiable assessment of hydrocarbon reserves for the corresponding reservoir classes in terms of permeability. The article discusses a methodology that allows you to perform all calculations in an automated mode. The text of the article provides the necessary description of the program for calculating the probabilities of exceeding the permeability thresholds, as well as a schematic diagram reflecting the main provisions of its work. The article substantiates the expediency of not using porosity thresholds for reservoir identification. Instead, permeability histograms are calculated for each cell. This methodological scheme makes it possible to calculate reserves associated with rocks of various permeability classes in an automatic mode. Keywords: bottomhole formation zone; asphalt-resin-paraffin deposits; nitrite composition; surfactants; enhanced oil recovery.

Dispersion model of NOx emissions from a liquefied natural gas facility

Natural gas used widely in terms of energy production. Energy production is among the most prominent sectors of humankind. Combustion processes inevitably produces air pollutants. The major pollutant during a combustion process is nitrogen oxide emissions. The term of nitrogen oxides primarily include nitrogen monoxide and nitrogen dioxide. These pollutants are generated regardless of the fuel content since air composition itself is the major source for these pollutants. It is possible to calculate emissions through the activity data and emission factors. Calculation of emissions is not enough for an environmental assessment. The impact of pollutants on human health relies on their concentration in the atmosphere. In order to determine their concentrations several modelling practices are developed. In this study, AERMOD used for modelling purpose of NOx emissions from a liquefied natural gas facility. It was observed that the pollutants were dispersed mostly towards south-southwest of the facility, where Marmaraereğlisi district is located. Although the pollutants transported directly to the settlement, the concentrations remained limited. During operation conditions, the highest daily NOx concentration was 1.7 μg/m3 and the highest annual concentration was 0.1 μg/m3. At maximum operating conditions, the highest daily NOx concentration was 16.2 μg/m3 and the highest annual concentration was 2.5 μg/m3. At minimum operating conditions, the highest daily NOx concentration was 1.1 μg/m3 and the highest annual concentration was 0.2 μg/m3.

A review of the status of air quality monitoring in the Permian Basin, USA, and its implications for effective long-term monitoring of industrial operations

The Permian Basin is the largest petroleum producing region in the United States. Few studies have investigated impact the Petroleum Industry had on the air quality of the Permian Basin. Industry operations in the Basin has two primary impacts on air quality, (a) it significantly contributes carbon dioxide (CO2) and methane (CH4) to the atmosphere during extraction, transport and use of fossil fuels, (b) industry operations influence public health especially when populations are in proximity to all categories of oil and gas facilities. The advent of Covid-19 in late 2019 and a severe drought that began prior to 2019 in West Texas have created unusual circumstances regarding air quality and public health in the Permian Basin. This study has monitored airborne pollen, spores, fungal spores, and other organically derived particles, and inorganic particulate matter (1, 2.5, 10-micron particulate matter (PM) and total suspended particles (TSP)), volatile organic compounds (VOCs), and sulfur dioxide (SO2). The pandemic caused a historic reduction in oil and gas production slowing operations in the Permian Basin to near zero during the study period, reducing environmental effects on air quality and concomitantly an increase in flaring of natural gas. Although there were increases in the release of VOCs fixed base monitors detected no notable increase. However, an increase in the concentration of airborne pollutants (VOCs and SO2) shows a close correlation with proximity to oil and gas facilities and the intensity of industry operations. This phenomenon is attributed to the highly local nature of flaring and CH4 plume emissions from leaking oil and gas facilities. Air quality improved in the Permian Basin due to reduction in production activity because of the Covid-19 pandemic, and the reduction of particulate matter due to the ongoing drought during the study period.

Optimization of software-controlled machining of critical pipe fittings

The quality requirements for pipeline fittings for NPPs and oil and gas facilities have become more stringent recently, which is related to ensuring their safe operation life. When manufacturing parts using subtractive machining technologies, special importance is attached to accuracy indicators of linear-angular dimensions and surface shapes. This study examines ways to optimize dimensional turning using the example of a “separator” part on a multifunctional CNC turning and milling center MULTICUT 630/2000S. Operations of designing and optimizing the production of parts are increasingly determined by the results of simulation modelling, virtual models, which, in fact, are an integral part of technological processes. In this work, simulation modelling is performed on simulators with CNC Sinumerik 810/840D/Operate Turn. This procedure is a simplified version of the Weiler-Atherton clipping algorithm as applied to stock removal turning. In addition to the algorithm, additional modules for dynamic corrections of control programs are proposed in order to guarantee the requirements of design documentation for accuracy in the conditions of a dynamic SPID system: machine – fixture – tool – part. The cutting speed, depth of cut and tool feed in turning have the greatest influence on the stock removal process from the technological control parameters. Modules of dynamic corrections of control programmes allow to estimate quite accurately the influence of control factors in turning (cutting speed, depth of cut and feed) on cutting force and machining accuracy.

Introduction of a carbon footprint assessment in the oil and gas facility life extension decision-making process

In large oil and gas producing countries, extraction and processing activities, including upstream activities, can represent a large share of domestic emissions. As oil fields approach their expected service life and reach depletion, energy use and GHG emissions increase per unit of produced oil, shifting operations away from their optimal point. Thus, it is paramount that oil field life extension decisions account for energy use and GHG emissions. However, many facilities are having their service life extended without considering this energy inefficiency and previous life extension decision making studies have neglected GHG emissions. Addressing this issue, this paper proposes the inclusion of a carbon footprint assessment within the evaluation of oil and gas offshore production facility life extension. The carbon footprint assessment adds an environmental lens to the evaluation of ageing, formerly evaluated according to material degradation, obsolescence and organizational issues. An eleven-stage framework is proposed to systematize the ageing related carbon footprint assessment and support life extension decision-making: (1) Objective definition, (2) Scope definition, (3) Field conditions description, (4) Scope breakdown into manageable portions, (5) Detailed data collection for each process and subsystem, (6) Input and output definition for each process and subsystem, (7) Process modelling, (8) Methodology definition for energy demand and inefficiency estimate, (9) Monitoring indicator definition, (10) Performance evaluation, and (11) Interpretation of results. The proposed framework is applied to a hypothetical case study, developed with data from a typical oil and gas offshore production platform operated in Brazil. Two LE improvement strategies were simulated, i.e. reducing the number of gas turbines, and increasing the export of natural gas. Both alter the modus operandi of the compression system and do not require additional equipment installation. These strategies resulted in a combined reduction of 922,000 tCO2 during the extended 10-year operation. This outcome demonstrates that by applying the framework opportunities for reducing energy use and GHG emissions during life extension can be identified and quantified, facilitating life extension decision-making.

Instrument Air Compressors: The Lifeline of Oil and Gas Facility. Volume 1. A Case Study of Oml 17 – Nigeria

Instrument air compressors (IACs) play a pivotal role as the backbone of oil and gas facilities, providing essential compressed air to power critical instruments and pneumatic systems. (Thomas Paulose, 2024). Instrument air is a critical component in the oil and gas industry. It is compressed air that is used to power instruments and control systems that are used in the production, processing, and transportation of oil and gas. (EY, 2020). This paper delves into the indispensable significance of IACs in ensuring the reliable and safe operation of oil and gas facilities, elucidating their crucial role in various operational processes, including control systems, safety devices, and process instrumentation. Through a thorough examination of the importance of instrument air in the oil and gas industry, this paper emphasizes the paramount importance of maintaining optimal performance and reliability of IACs. It discusses the key challenges and considerations associated with ensuring the continuous supply of instrument air, encompassing equipment reliability, energy efficiency, and maintenance practices. Furthermore, the paper explores effective strategies for optimizing instrument air compressor performance, encompassing proactive maintenance, technological advancements, and operational enhancements. (Abhishek Kumar et al 2021). Utilizing case studies and real-world examples, the paper illustrates the profound impact of proficient instrument air compressor management on overall facility reliability, safety, and operational efficiency. In conclusion, this paper underscores the critical recognition of instrument air compressors as indispensable assets within oil and gas facilities. (EY, 2020). It emphasizes the imperative for proactive management and optimization to uphold their continued reliability and efficacy. (Paul J. Holdcroft et al, 2015) By prioritizing the maintenance and performance of IACs, oil and gas operators can elevate facility operations, mitigate risks, and uphold the industry's commitment to safety and environmental stewardship.