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Mechanism analysis and technical scheme optimization on CO2 displacement and CO2 storage are based on the high-pressure physical properties of CO2-added formation oil. Oil and natural gas samples from the BZ25-1 block in the Bohai oilfield were used to conduct high-pressure physical property experiments to explore the impacts of CO2-CH4 mixed gas on the properties of formation oil. After injecting different amounts of mixed gas, the saturated pressure was measured by constant mass expansion test, the viscosity was measured by falling ball method, the expansion coefficient was measured by gas injection expansion test, and the gas–oil ratio and volume coefficient were obtained by single degassing test. The results show that with gas injection, the saturation pressure and dissolved gas–oil ratio of formation oil increase, the volume coefficient and expansion factor go up, while the oil viscosity reduces. With the increase in gas addition, the properties of formation oil continue to improve, but the increase in improvement becomes flat. With the increase in pressure, the amount of dissolved gas in the formation oil will also increase. High-purity CO2 is more helpful to change the properties of formation oil, while the gas mixed with CH4 is more beneficial to elevate the formation energy. For the BZ 25-1 block, the gas injection amount of about 80 mol% is appropriate and the CO2 purity of 60% can well balance the oil properties improvement and the formation pressure elevation. [ABSTRACT FROM AUTHOR]

This study evaluated multiple commercially available continuous monitoring (CM) point sensor network (PSN) solutions under single-blind controlled release testing conducted at operational upstream and midstream oil and natural gas (O&G) sites. During releases, PSNs reported site-level emission rate estimates of 0 kg/h between 38 and 86% of the time. When non-zero site-level emission rate estimates were provided, no linear correlation between the release rate and the reported emission rate estimate was observed. The average, aggregated across all PSN solutions during releases, shows 5% of the mixing ratio readings at downwind sensors were greater than the site's baseline plus two standard deviations. Four of seven total PSN solutions tested during this field campaign provided site-level emission rate estimates with the site average relative error ranging from −100% to 24% for solution D, −100% to −43% for solution E, −25% for solution F (solution F was only at one site), and −99% to 430% for solution G, with an overall average of −29% across all sites and solutions. Of all the individual site-level emission rate estimates, only 11% were within ±2.5 kg/h of the study team's best estimate of site-level emissions at the time of the releases. [ABSTRACT FROM AUTHOR]

Accurate and comprehensive quantification of oil and gas methane emissions is pivotal in informing effective methane mitigation policies, while also supporting the assessment and tracking of progress towards emissions reduction targets set by governments and industry. While national bottom-up source-level inventories are useful for understanding the sources of methane emissions, they are often unrepresentative across spatial scales, and their reliance on generic emission factors produces underestimations when compared with measurement-based inventories. Here, we compile and analyze previously reported ground-based facility-level methane emissions measurements in the major US oil and gas producing basins and develop representative methane emission profiles for key facility categories in the US oil and gas supply chain, including well sites, natural gas compressor stations, processing plants, crude oil refineries, and pipelines. We then integrate these emissions data with comprehensive spatial data on national oil and gas activity to estimate each facility's mean total methane emissions and uncertainties, from which we develop a mean estimate of national methane emissions, resolved at 0.1° × 0.1° spatial scales (~10 km × 10 km). From this measurement-based methane emissions inventory (EI-ME), we estimate total US national oil/gas methane emissions of 15.7 Tg (95 % confidence interval of 14–18 Tg) in 2021 which is 2.5 times greater than the EPA Greenhouse Gas Inventory. Our estimate represents a mean gas production-normalized methane loss rate of 2.6 %, consistent with recent satellite-based estimates. We find significant variability in both the magnitude and spatial distribution of basin-level methane emissions, ranging from <1 % methane loss rates in the gas-dominant Appalachian and Haynesville regions to >3–6 % in oil-dominant basins, including the Permian, Bakken, and the Uinta. Additionally, we present and compare novel comprehensive wide-area airborne remote sensing data and results of total area methane emissions and the relative contributions of diffuse and concentrated methane point sources as quantified using MethaneAIR in sub-regions of the Permian and Uinta basins that together indicate diffuse area sources accounting for the majority of total regional oil and gas emissions. Our assessment offers key insights into plausible underlying drivers of basin-to-basin variabilities in oil and gas methane emissions, emphasizing the importance of integrating measurement-based data in developing high-resolution, spatially explicit methane inventories in support of accurate methane assessment, attribution, and mitigation. The high-resolution spatially explicit EI-ME inventory is publicly available at https://doi.org/10.5281/zenodo.10734300 (Omara et al. 2024). [ABSTRACT FROM AUTHOR]

We examine the impact of oil price uncertainty on IPO volume in the oil and gas sector. By using the implied volatility of oil options, a forward-looking uncertainty measure, we identify the effect of uncertainty on the going-public decision. Oil price uncertainty exhibits a strong negative relation to IPO volume. A one standard deviation decrease in the implied volatility results in a 29% increase in the number of quarterly IPOs. The effect is concentrated among the price-sensitive upstream producers. We further report that uncertainty positively impacts the IPO withdrawal decision and increases the value of postponing the offering. Keywords: Energy economics, IPOs, Implied crude oil volatility, Oil and gas sector, Oil price uncertainty, 1. INTRODUCTION Oil price uncertainty can affect both firms' investment and financing decisions. The impact of oil price uncertainty on investments in the oil and gas sector is well documented [...]

Reservoir simulation is known as perhaps the most widely used, accurate, and reliable method for field development in the petroleum industry. An integral part of a reliable reservoir simulation process is to consider robust and rigorous tuned EOS models. Traditionally, EOS models are tuned iteratively through arduous workflows against experimental PVT data. However, this comes with a number of drawbacks such as forcingly using weight factors, which upon alteration adversely affects the optimization process. The objective of the current work is thus to introduce an auto-tune PVT matching tool using NSGA-II multi-objective optimization. In order to illustrate the robustness of the presented technique, three different PVT samples are used, including two black-oil and one gas condensate sample. We utilize Peng-Robinson EOS during all the manual and auto-tuning processes. Comparison of auto-tuned EOS-generated results with those of experimental and computed statistical error values for these samples clearly show that the proposed method is robust. In addition, the proposed method, contrary to the manual matching process, provides the engineer with several matched solutions, which allows them to select a match based on the engineering background to be best amenable to the problem at hand. In addition, the proposed technique is fast, and can output several solutions within less time compared to the traditional manual matching method. [ABSTRACT FROM AUTHOR]

In the southern thrust belt (STB) of Junggar Basin, hydrocarbon resources are abundant at ultradeep depths. The genesis of highly mature oil and gas is complex, with considerable geological implications, because of the burial depth of these resources and multiphase tectonic evolution. The deep–ultradeep oil and gas reservoir accumulation processes and the contribution of Permian source rocks are still unclear in the STB. In this study, using the ultradeep reservoirs of the middle section of the STB (MSTB) as an example, systematic evaluations were conducted on the hydrocarbon geochemical characteristics of the area. Additionally, this study detailed the accumulation and evolution processes of the reservoir in the lower play of the MSTB using various comprehensive technical analyses, such as those for the geochemical characteristics of crude oil, the genesis and source of crude oil and gas, inclusion observations, homogenization temperature, quantitative particle fluorescence, and basin simulation. The integrated analysis results showed that the oil and gas from Well HT-1 in Huxi Anticline (HXA) in the lower play was characterized by mixed sources from Permian argillaceous source rock and Jurassic coal-bearing source rocks. The pristane/phytane ratio (Pr/Ph) and biomarkers of the crude oil indicated the presence of Permian source crude oil. The natural gas drying coefficient and the carbon isotope of methane conveyed a typical coal-related gas from the Lower–Middle Jurassic epoch. In addition, three types of hydrocarbon inclusions (yellow–green fluorescence, blue–white fluorescence, and gaseous hydrocarbons) were developed in the MSTB. Oil and gas accumulation periods included Early Cretaceous, Eocene, and Miocene. Finally, substantial deviations were found for accumulation periods from different anticlines in the study area, which were controlled by the ancient structural background and tectonic evolution. The early anticlines, formed by Yanshanian tectonic movement (YSTM), controlled the early hydrocarbon migration as well as reservoir formation, and the newer anticlines, formed by Himalayan tectonic movement (HMTM), controlled the redistribution of hydrocarbons from ancient reservoirs. The oil and gas reservoir formed in Qingshuihe Formation (K1q) in HXA occurred during the Miocene. The ancient oil reservoirs to the south of HXA were damaged, and hydrocarbons were redistributed; the hydrocarbons migrated and accumulated in HXA and mixed with highly mature gas from Jurassic source rocks. The Permian hydrocarbons made a substantial contribution to the deep–ultradeep resources of MSTB and provided extremely rich hydrocarbon resources together with the Jurassic source rocks. Additionally, within MSTB, large anticlines were thoroughly developed in ultradeep strata, which provided superior trapping conditions for large-scale hydrocarbon accumulation. [ABSTRACT FROM AUTHOR]

The discovery of the Bozhong 19-6 gas field has opened a new frontier for deep gas exploration in the Bohai Bay Basin, with a great potential for further gas exploration. However, poor understanding of oil and gas origin has been limiting the exploration progress in this area. To clarify the origin of condensate oil and gas in Bozhong 19-6 gas field, this study adequately utilized the organic geochemical analysis data to investigate the composition and geochemical characteristics of condensate oil and natural gas, and analyzed the relationship between condensate oil and the three sets of source rocks in the nearby subsags. Results show that the lighter components dominate the condensate oil, with a forward type predominance. The parent material of crude oil was primarily deposited in a shallow, clay-rich, low-salinity, weakly reducing aquatic environment. The condensate and natural gas have similar parent source characteristics and maturity, with Ro ranging from 1.4% to 1.6%. Both are products of high maturity stage, indicating that they are hydrocarbon compounds produced by the same group of source rocks in the same stage. Oil-sources correlation shows that condensate oil and gas mainly originate from the source rocks of the third member of Shahejie Formation in the nearby subsags of the Bozhong 19-6 structural belt. [ABSTRACT FROM AUTHOR]

Hydrogen sulfide (H2S) and carbon dioxide (CO2) present in oil and natural gas cause mild steel corrosion, potentially resulting in formation of corrosion product layers on the internal surfaces of tubulars. In field experiences relating to the research reported herein, this has led to restrictions on the flow of water produced from a three-phase horizontal separator. This paper demonstrates a specific case of chemical removal of relatively hard, dark, and adherent heterogeneous deposits on the internal surface of the pipe. The phases involved in this process are iron sulfide, iron oxides and calcium carbonate existing as scales/corrosion products. To evaluate their dissolution, laboratory tests were conducted using hydrochloric acid (HCl) with additions of chlorine in the form of calcium hypochlorite [Ca(ClO)2]. Appropriate safety measures were taken employed, considering hazards associated with chlorine and toxicity of hydrogen sulfide. The treatment regime had 87 % effectiveness for scale removal in combination with propargyl alcohol (2-propyn-1-ol) as a corrosion inhibitor. [ABSTRACT FROM AUTHOR]

Indonesia has a target of producing 1 million BOPD of oil and 12 BSCFD of natural gas in 2030. The strategy for achieving the production target in 2030 is transformation from resources to production, accelerating chemical EOR, massive connectivity for finding large wells, and optimizing field production. In optimizing existing field production, one of the supporting factors is production facilities, so production facilities with good integrity are needed to minimize upplanned shutdowns. One of the oil and gas installations that pose a high risk is the installation of oil and gas pipelines. The existing pipeline installation in the Java Sea, from North Cirebon to the Seribu Islands, has an area of 8300 km2 and is operated by PT XYZ. Therefore, it requires complete and accurate inspection data to find out. This research method uses a modification of the Kent Mulhbauer scoring index. The risk level of the three subsea pipelines at Company XYZ, namely 4 in Gas Line Mike Mike, 8 in Gas Line Echo pipeline, and 8 in Gas Line Mike Mike pipeline, is found to be in the very highrisk category. The inspection strategy carried out for the third pipe with a very high risk category is visual inspection (ROV), freespan assessment, cathodic protection check (CP), UT thickness inspection on the riser and elbow (topside and subsea), and UT thickness inspection on the bottom pipe sea using the NACE ICDA method for thickness taking points and inspection periods once every 4 years or based on risk-based inspection (RBI). The cost and effort of examining the strategy will be assessed directly with the level of the risk category. Because of this, so that the inspection of the strategy can be optimal, effective, and efficient, it is divided into 3 (three) risk categories, namely low, medium, and high/very high, where the selection of strategy inspection is appropriate with the level of risk. The results of this study are expected to be a reference in making a policy or regulation to carry out regular inspections of underwater pipelines by using the risk analysis method to determine the inspection strategy. [ABSTRACT FROM AUTHOR]

During the WWI the oil needs of the Romanian army became essential in the context of the retreats towards Eastern Romania, in Moldova. Geologist lon Popescu-Voiteşti was asked to find solutions to increase the oil production and he proposed to deepen the wells of certain oilfields such as Solonj-Stăneşti or Zemes, with excellent results. Based on this precedent, for a quarter of a century, the geological scientist turned professor at the University of Cluj, remained concerned with the issue of hydrocarbon fields in Romania. The results of that work were included in a series of publications, the last book published just one year before his sudden death being a synthesis on this topic. This paper exposes the main ideas which can be find in the publications issued between 1916 and 1943, which explain Voitesti's proposed approaches to the professional challenges of the oil and gas fields in Romania [ABSTRACT FROM AUTHOR]

Latin America and the Caribbean are one of the most unequal regions in the world, with high levels of poverty and reduced state capacity to solve structural problems. In this paper, we examined the existence of a β-convergence process between countries (i.e., reduction of disparities) in terms of energy poverty indicators. For this, we construct an annual panel of countries for the last six decades and for thirteen energy poverty indicators covering three dimensions (access, quality, and affordability). The results indicate that a convergence process has taken place between countries of Latin America and the Caribbean, which includes all the dimensions analyzed (i.e., the countries of the region have become more similar in terms of energy poverty over time). Context-specific recommendations that emerge from the findings aim at promoting greater adoption of renewable energy, reducing delays in obtaining an electricity connection, and cutting subsidies for natural gas and oil. [ABSTRACT FROM AUTHOR]

The authors studied the problem of naphthenate deposits in the oil and gas industry. Currently, there are few ways available to inhibit or dissolve naphthenate deposits in oil facilities. Naphthenate deposits can block pipelines and aggregate in other parts of the installation, i.e., in the separators. In Europe, the issue of deposition on oil rigs is commonly encountered in Norway and the United Kingdom, as well as in some African countries, i.e., Angola and Nigeria. Many tons of chemicals are used to combat naphthenate deposition, usually through inhibition, but also via the dissolution of the scale that precipitates over time. The presented work examines the characteristics of naphthenate fouling, historical ways to inhibit it, and current approaches to the problem, as well as the results of the laboratory testing of naphthenate inhibitors and solvents. The process of the naphthenate creation is as follows. When oil exhibits a high TAN (total acid number) and high content of salty water, naphthenate deposits can emerge via the reaction of naphthenic acids and metal salts (mostly calcium ones). Naphthenates are partially insoluble in water, and they usually float below the oil/water interface. The standard methods of naphthenate inhibition involve lowering the pH of the production water, which can result in serious problems, especially related to corrosion. This study addresses experiments conducted in the laboratory in Poland and on oil rigs in Angola and is based on contemporary knowledge and standards. The objective of this paper was to investigate the most suitable naphthenate inhibitors and solvents, as well as to undertake bottle tests of naphthenate inhibitors with a focus on the main indicators (water clarity, quality of separation surface, and clarity of oil). The use of citric and formic acids in this paper is a novelty, and it is compared with the results obtained with the more commonly used acetic acid, hydrochloric acid, and ABS acid. It was proven that formic acid can effectively inhibit and dissolve naphthenic deposits (99% efficiency of inhibition and 100% efficiency of dissolution). It was found that some acids used in naphthenate inhibition create more deposits than were originally present. Formic acid and ABS acid yielded significantly better results than other types. It is also here hypothesized that there are substances other than acids that can effectively remove naphthenate deposits, and the other novelty of this study is in the use of mutual solvents in the removal of naphthenate salts. Another important outcome is the finding that not only acids but also mutual solvents (EGMBE and isopropyl alcohol) can effectively remove naphthenate deposits. The test results show that formic acid dissolved all of the naphthenates, while citric acid had 97% efficacy, isopropyl alcohol had 95% efficacy, and EGMBE showed 94% efficacy. The impacts of commercial naphthenate inhibitors on the bottle test results and interfacial tension measurements were also investigated. It was shown that commercial naphthenate inhibitors can decrease the interfacial tension between oil and water by more than 30% when used at dosages of 400 ppm. [ABSTRACT FROM AUTHOR]

Unlike carbon footprint in fossil fuel usage, few studies have investigated carbon footprint in the upstream petroleum industry. Currently, there is no published offshore carbon footprint study, and the carbon footprint of unmanned offshore platforms in Indonesia remains unclear. This study aims to identify the potential carbon footprint of offshore platforms in the Madura Field during offshore production based on the data activity using the life cycle approach. The data inventory had been monitored for a one-year natural gas production cycle from four unmanned platforms and one processing platform in Madura Field. The results show that the unmanned offshore platforms generated an average of 98.77 kg CO2eq/GJ with a high deviation (± 3.34). The processing platform's average carbon footprint is 1232 kg CO2eq/GJ, which indicates the wide carbon footprint range between production platforms. Carbon footprint in the offshore platform is essential for completing the cradle to grave footprint identification since it is one of the important environmental sustainable indicators used as environmental evaluation tools. Understanding the footprint level in the upstream petroleum industry is significant for studying climate change's impact on offshore activity, potential carbon generation released to the environment, and the key step of establishing a carbon reduction plan for the petroleum industry. Therefore, climate sustainability evaluation in the upstream petroleum industry can be assessed continuously. [ABSTRACT FROM AUTHOR]

This study empirically investigates the asymmetric effects of spot (future) prices and storage on rig counts in the US natural gas and crude oil markets from January 1986 to May 2020. It adopts the Nonlinear Autoregressive Distributed Lag (NARDL) model and establishes a flexible and efficient framework that measures the effects of positive and negative shocks in each of these variables on rig counts while modeling possible asymmetries in both the short and long term. For the natural gas market, the results reveal significant long-term asymmetric effects of spot (future) gas prices and storage on gas rigs. The positive and statistically significant cumulative effect of changes in natural gas storage suggests that larger natural gas storage has caused changes in the use of natural gas drilling rigs. For the crude oil market, we find significant short-term asymmetric effects of spot (future) gas prices and oil stocks on oil rigs. Furthermore, in addition to the optimal price and level of storage, the cost, as proxied by the interest rate, is a crucial determinant in rig drilling decision-making in the energy sector. [ABSTRACT FROM AUTHOR]

A breakthrough has been made in the recent exploration of the deep oil and gas bearing system in the eastern belt around the Penyijingxi sag of the Junggar Basin. These reservoirs are characterized by mixed sources and multi-stage accumulation. However, this process has not been thoroughly investigated, limiting our understanding of the fundamental rules of hydrocarbon migration and accumulation and making it difficult to determine exploration plans. This study mainly reconstructs this process using biomarkers, carbon isotopes, light hydrocarbons, and fluid inclusions. According to the biomarkers and carbon isotopes for oil-source correlation, Permian crude oil is a mixed-source oil from the Fengcheng Formation (P1f) and the Xiawuerhe Formation (P2w) source rocks, while Jurassic crude oil originates from the P2w source rock. The carbon isotope and light hydrocarbon data demonstrate that Jurassic natural gas has a mixed-gas characteristic with a preponderance of coal-type gas, in contrast to Permian natural gas, which is primarily oil-type gas. The hydrocarbon charging events in the study area were reconstructed based on a comprehensive investigation of the hydrocarbon generation history of source rocks, the homogenization temperature of fluid inclusion, and the burial history of the reservoir. According to the model, the P1f and P2w source rocks have made contributions to the current regional oil reservoirs, which provides targets for future exploration. [ABSTRACT FROM AUTHOR]

A breakthrough was made in tight marlstone reservoirs from an evaporative lagoon in the second sub-member of the third member of the Leikoupo Formation (Lei3-2) in the Central Sichuan Basin. The source rock characteristics, reservoir characteristics of the marlstone and geochemical parameters of the oil and natural gas were investigated to evaluate the unconventional hydrocarbon exploration potential of the tight marlstone from the evaporative lagoon. The results revealed that the source rocks were deposited in evaporative lagoon environments, and the average total organic carbon (TOC) content value for the samples was 0.75 wt%. The thermal maturity of the organic matter was relatively high, with a calculated vitrinite reflectance (Rc) of 1.7%. The characteristics of marlstones suggest that the potential source rocks had fair to good hydrocarbon generative potential. The condensate samples had low densities, low viscosities and high thermal maturity, with a Rc value of 1.7%. For the natural gas, the dry coefficient was around 0.90, and the carbon isotopic compositions of methane and ethane was −41.3‰ and −28.4‰, respectively. According to the carbon isotopic compositions, thermal maturity and geological background, the oil and natural gas from Lei3-2 are comparable with the marlstone of Lei3-2. Thus, the oil and natural gas is self-sourced and originates from the marlstone in the Lei3-2. Micropores and microfractures are often detected in the marlstone from Lei3-2, and a gypsum layer is conducive to the hydrocarbon preservation. These results suggest that the evaporative lagoon facies in Lei3-2 have large, self-sourced, unconventional, tight marlstone reservoir potential. This study also enhances the prospects for further oil and gas exploration of evaporative lagoon facies in other basins. [ABSTRACT FROM AUTHOR]

This manuscript deals with a novel, nonlinear, and non-stationary stochastic model with symmetric, Laplacian distributed innovations. The obtained model, named Laplacian Split-BREAK (LSB) process, is intended for dynamic analysis of time series with pronounced and permanent fluctuations. By using the method of characteristic functions (CFs), the basic stochastic properties of the LSB process are proven, with a special emphasis on its asymptotic behaviour. The different procedures for estimating its parameters are also given, along with numerical simulations of the obtained estimators. Finally, it has been shown that the LSB process, as an adequate stochastic model, can be applied in the analysis of dynamics in the world market of crude oil and natural gas. [ABSTRACT FROM AUTHOR]

Background: Oil rents (OR) and natural gas rents (NGR) have significant contributions to the income of the Middle East and North Africa (MENA) economies and may increase emissions. Moreover, spatial autocorrelation is expected in carbon dioxide (CO2) emissions due to the geographically closed economies in the MENA region. Thus, we examine the impact of OR and NGR on CO2 emissions caring spatial dimensions and analyze the environmental Kuznets curve (EKC). Methods: We apply the spatial Durbin model technique on the effects of OR, NGR, and economic growth on CO2 emissions in 17 MENA nations from 2000-2019, i.e., Algeria, Bahrain, Egypt, Iran, Iraq, Israel, Jordan, Kuwait, Libya, Morocco, Oman, Qatar, Saudi Arabia, Syria, Tunisia, the United Arab Emirates (UAE), and Yemen. Moreover, diagnostic tests are applied to reach the most appropriate spatial specification and to have the most robust results. Results: The results disclose that CO2 emissions have spillovers and emissions of any country can damage the environment of neighboring countries. The EKC is corroborated with a turning point of 38,698 constant 2015 US dollars. Israel and Qatar are in 2nd phase of the EKC, and 15 MENA economies are in 1st stage. Thus, the economic expansion of most economies has ecological concerns. The effect of natural gas rents is found statistically insignificant. Oil rents have minute negative effects on emissions of local economies with an elasticity coefficient of -0.2117. Nevertheless, these have a positive indirect effect with an elasticity coefficient of 0.5328. Thus, the net effect of oil rents is positive. One percent increase in oil rents could accelerate 0.3211% of emissions. Thus, we suggest the MENA countries reduce reliance on oil rents in their income to avoid the negative environmental effects of the oil sector. [ABSTRACT FROM AUTHOR]

Natural gas injection is considered for enhanced oil recovery (EOR) in a high saturation pressure reservoir in block B111 of the Dagang oilfield, China. To investigate the interaction characteristics of injected natural gas and crude oil, the ability for dissolution–diffusion and miscibility–extraction of natural gas in crude oil was tested using a piece of high-temperature and high-pressure PVT equipment. The physical properties and minimum miscible pressure (MMP) of the natural gas–crude oil system and their interaction during dynamic displacement were analyzed using the reservoir numerical simulation method. The results show the following: (1) Under static gas–oil contact conditions, natural gas has a significant dissolution–diffusion and miscibility–extraction effect on the crude oil in block B111, especially near the gas–oil interface. The content of condensate oil in gas phase is 10.14–18.53 wt%, while the content of dissolved gas in oil phase reaches 26.17–57.73 wt%; (2) Under the reservoir's conditions, the saturated solubility of natural gas injected in crude oil is relatively small. The effect of swelling and viscosity reduction on crude oil is limited. As the pressure increases with more natural gas dissolved in crude oil, the phase state of crude oil can change from liquid to gas; accordingly, the density and viscosity of crude oil will be greatly reduced, presenting the characteristics of condensate gas; (3) The MMP of natural gas and crude oil is estimated to be larger than 40 MPa. It mainly forms a forward-contact evaporative gas drive in block B111. The miscible state depends on the maintenance level of formation pressure. The injected natural gas has a significant extraction effect on the medium and light components of crude oil. The content of C2–C15 in the gas phase at the gas drive front, as well as the content of CH4 and C16+ in the residual oil at the gas drive trailing edge, will increase markedly. Accordingly, the residual oil density and viscosity will also increase. These results have certain guiding significance for understanding gas flooding mechanisms and designing gas injection in block B111. [ABSTRACT FROM AUTHOR]

Indonesia has Undang-Undang Dasar Negara Republik Indonesia 1945 (UUD NRI 1945), Chapter 33 (3) UUD NRI 1945 give a mandate to the state that is equipped with the right to control the state as an instrument to achieve one of the highest goals of establishment Negara Kesatuan Republik Indonesia (NKRI), that is: promote the general welfare. The state represented by BP Oil and gas and then SKK Oil and gas, is in an unequal position with private legal entities in the upstream oil and gas business. The concept of the relationship between the state and private legal entities in the management of oil and gas is deemed by the MK to be inappropriate or contrary to the meaning Chapter 33 (3) UUD NRI 1945, which causes the lack of realization of oil and gas management for the greatest prosperity of the people. Management of oil and gas resources that are not in line or contrary to meaning Chapter 33 (3) UUD NRI 1945 can cause the goal of the greatest prosperity of the people not to be achieved. In the management so far, it is difficult to realize the nature of the constitutional management of oil and gas resources, this occurs because the Government of Indonesia as the representative of the state is apparently unable to maintain state sovereignty and adequate state control rights in the presence of foreign contractors involved in the management of oil and natural gas resources. through cooperation contracts due to ignoring priorities to government agencies such as independent BUMN. BUMN must dominate the management of oil and gas as strategic natural wealth in Indonesia, so that state sovereignty and the right to control the state can be used for the greatest prosperity of the people without third party intervention. [ABSTRACT FROM AUTHOR]

With recent advancements in the petroleum industry, the need for multiphase pumps to transport multiphase products, such as the product of oil, water, and natural gas, arises along with their challenges. A helico-axial multiphase pump should be capable of converting fluid kinetic energy into pressure by avoiding gas–liquid separation and the gas-locking phenomenon, enabling smooth pump operation at higher gas volume fractions. In this paper, erosion on a helico-axial pump is evaluated at different flow conditions using sand particles mixed with water. A very important practical finding of this investigation is that the erosion rate increased when the flow conditions deviated from the design point of 3600 RPM. Operating the pump in off-design conditions not only reduced its hydraulic efficiency but also increased the erosion rates and hence reduces its life. It was observed that at 4800 RPM, the pump efficiency decreased by 11% and the erosion rate increased by 80%. This increase in erosion rate was attributed to the formation of local vortices upstream of the blade leading edge affecting the particle flow path and increasing its impact on the blade surface. [ABSTRACT FROM AUTHOR]

Direct measurements of methane emissions at the component level provide the level of detail necessary for developing actionable mitigation strategies. As such, there is a need to understand the magnitude of component level methane emission sources and test methane quantification methods that can capture methane emissions from component level sources. The static chamber method is a direct measurement technique that is being applied to measure large and complex methane sources such as oil and gas infrastructure. In this work we compile component level methane emission factors from the IPCC emission factor database to understand the magnitude of component level methane flowrates, review the tested flowrates and measurement techniques from 38 controlled release experiments, and perform 64 controlled release testing of static chambers methodology with mass flowrates of 1.02, 10.2, 102, and 512 grams of methane per hour (g/hour). We vary the leak properties, chamber shape, chamber size, and usage of fans to evaluate how these factors affect the accuracy of the static chamber method. We find that 99% of component level methane emission rates from the IPCC emission factor database are below 100 g/hour, and that 77% of previously-available controlled release experiments did not test for methane mass flowrates below 100 g/hour. We find that the static chamber method quantified methane flowrates with an overall accuracy of ±14%, and that optimal chamber configurations (i.e., chamber shape, volume, usage of fans) can improve accuracy to below ±5%. We find that smaller chambers (=20 L) performed better than larger volume chambers (=20 L), regardless of the shape of chamber or usage of fans. However, we found that the usage of fans can substantially increase the accuracy of larger chambers, especially at higher mass flowrates of methane (=100 g/hour). Overall, our findings can be used to engineer static chamber systems for future direct measurement campaigns targeting a wide range of sources, including landfills, manholes, and oil and natural gas infrastructure. [ABSTRACT FROM AUTHOR]

Natural gas flaring, with its harmful environmental, health, and economic effects, is common in the Nigerian oil and gas industry because of a lower tax regime for flared gases. Based on the adverse effects of flared gas, the Nigerian government has renewed and improved its efforts to reduce or eliminate gas flaring through the application of natural gas utilisation techniques. However, because the conventional approach to flare gas utilisation is heavily reliant on achieving scale, fuel, and end-product prices, not all technologies are technically and economically viable for typically capturing large and small quantities of associated gas from various flare sites or gas fields (located offshore or onshore). For these reasons, this paper reviews and compares various flare gas utilisation options to guide their proper selection for appropriate implementation in the eradication of routine gas flaring in Nigeria and to promote the Zero Routine Flaring initiative, which aims to reduce flaring levels dramatically by 2030. A qualitative assessment is used in this study to contrast the various flare gas utilisation options against key decision drivers. In this analysis, three natural gas utilisation processes—liquefied natural gas (LNG), gas to wire (GTW), and gas to methanol (GTM)—are recommended as options for Nigeria because of their economic significance, technological viability (both onshore and offshore), and environmental benefits. All these gas utilisation options have the potential to significantly reduce and prevent routine gas flaring in Nigeria and can be used separately or in combination to create synergies that could lower project costs and product market risk. This article clearly identifies the environmental benefits and the technical and economic viability of infrastructure investments to recover and repurpose flare gasses along with recommendation steps to select and optimise economies of scale for an associated natural gas utilisation option. [ABSTRACT FROM AUTHOR]

As oil and natural gas production continue to go deeper into the ocean, the flexible riser, as a connection to the surface of the marine oil and gas channel, will confront greater problems in its practical application. Composite materials are being considered to replace steel in the unbonded flexible pipe in order to successfully meet the lightweight and high-strength criteria of ultra-deep-water oil and gas production. The carbon-fiber-reinforced material substitutes the steel of the tensile armor layer with a greater strength-to-weight ratio. However, its performance in deep-water environments is less researched. To investigate the mechanical response of a carbon fiber composite flexible riser in the deep sea, this study establishes the ABAQUS quasi-static analysis model to predict the performance of the pipe. Considering the special constitutive relations of composite materials, the tensile stiffness of steel pipe and carbon fiber-reinforced composite flexible pipe are predicted. The results show that the replacement of steel strips with carbon fiber can provide 85.06% tensile stiffness while reducing the weight by 77.7%. Moreover, carbon-fiber-reinforced strips have a lower radial modulus, which may not be sufficient to cause buckling under axial compression, so the instability of the carbon fiber composite armor layer under axial compression is further studied in this paper; furthermore, the characteristics of axial stiffness are analyzed, and the effects of the friction coefficient and hydrostatic pressure are discussed. [ABSTRACT FROM AUTHOR]

Consequently, oil and gas refining leads through the combination of several physical, chemical, and thermodynamic processes to the formation of many valuable products including fuels, materials, chemicals, and/or heat and power. The empirical analysis is performed using a novel state-of-the-art generalized sup ADF (GSADF) approach on six commonly used fuel price series, such as LDO (light diesel oil), HSD (high-speed diesel), petrol, natural gas, kerosene, and MS (motor spirit). Natural gas processing is designed to refine the raw gas by eliminating impurities, thus producing dry natural gas compliant to the pipeline gas quality specifications. Petroleum is considered the black gold of the earth, but this treasure cannot be utilized without the usage of innovative and advanced technologies for its recovery and conversion. [Extracted from the article]

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We use satellite methane observations from the Tropospheric Monitoring Instrument (TROPOMI), for May 2018 to February 2020, to quantify methane emissions from individual oil and natural gas (O/G) basins in the US and Canada using a high-resolution (∼25 km) atmospheric inverse analysis. Our satellite-derived emission estimates show good consistency with in situ field measurements (R=0.96) in 14 O/G basins distributed across the US and Canada. Aggregating our results to the national scale, we obtain O/G -related methane emission estimates of 12.6±2.1 Tg a -1 for the US and 2.2±0.6 Tg a -1 for Canada, 80 % and 40 %, respectively, higher than the national inventories reported to the United Nations. About 70 % of the discrepancy in the US Environmental Protection Agency (EPA) inventory can be attributed to five O/G basins, the Permian, Haynesville, Anadarko, Eagle Ford, and Barnett basins, which in total account for 40 % of US emissions. We show more generally that our TROPOMI inversion framework can quantify methane emissions exceeding 0.2–0.5 Tg a -1 from individual O/G basins, thus providing an effective tool for monitoring methane emissions from large O/G basins globally. [ABSTRACT FROM AUTHOR]

Energy prices are generally more volatile than the prices of other commodities. This is because shortterm energy demand responds more quickly to the impact of economic growth than to price changes. This paper aims to analyse this phenomenon. Therefore, when an energy shock occurs, an important price change may be necessary to influence the market. Currently such shock has been caused by the COVID-19 pandemic, which has produced the biggest sustained change in demand since World War II. In the medium to long term, energy prices will rise if investment will not be on an upward trend, which seems unlikely given the current environmental protection guidelines adopted by many countries around the world. In our paper we argue that supply and demand shocks and high price volatility are likely to continue to weigh on the energy market and the global economy. [ABSTRACT FROM AUTHOR]