Increase Oil Production Research Articles

Research on the stimulation mechanism of well shut-in imbibition and parameter optimization during fracturing-flooding

ABSTRACT In the development of low-permeability tight oil reservoirs, fracturing-flooding technology, with its dual advantages of “fracture creation and energy replenishment, and displacement by imbibition,” effectively addresses challenges such as poor water injection and low oil recovery. However, the mechanism of oil-water migration within the reservoir and the enhanced oil recovery during the shut-in imbibition process remain unclear, and the construction parameters are primarily based on empirical data. In this study, focusing on the Y block in the Bohai Bay Basin, eastern China, we conducted dynamic imbibition experiments and utilized nuclear magnetic resonance (NMR) technology to analyze the key factors influencing imbibition-driven oil displacement and the microscopic oil-water migration mechanisms within the pore space. Numerical simulation was then employed to optimize the construction parameters for fracturing-flooding operations. The results indicate that displacement and imbibition primarily occur in medium-sized pores, while the poor connectivity of micro- and small-sized pores leads to suboptimal effects. The shut-in process provides favorable conditions for imbibition displacement, allowing oil in small and medium pores to be further displaced into fractures. The main factors affecting imbibition efficiency include core permeability (optimal range: 1.5 mD to 4 mD), fracture length (approximately 2/3 of the core length), fracturing-flooding fluid concentration (optimal around 0.2%), and shut-in time (optimal range: 24 to 48 hours). Based on production capacity simulations, the optimal construction parameters for the Y block include an injection rate of 1152 to 1440 m3/min, a total injection volume of 20,000 to 25,000 m3, and a shut-in time of 30 to 45 days. The application of these optimized parameters resulted in an increase in the average daily oil production in the Y block from 4.4 tons to 7.7 tons, demonstrating a significant enhancement in reservoir productivity and oil recovery.

Optimal allocation of production quotas using an inverse DEA integrated with lean production capacity and negative data

In the past decade, the petroleum industry has faced two significant oil price crashes. The first occurred in 2014, driven by increased U.S. production, geopolitical shifts, and changes in OPEC policies. The more recent crash in 2020 was a consequence of the COVID-19 pandemic. Despite these secondary factors, industry experts widely attribute both crashes to excessive crude oil production. Considering this and aiming to prevent recurrences of unexpected price crashes in the future, this paper proposes a novel application of inverse DEA for optimizing OPEC production quotas. In this study, two versions of the inverse DEA are proposed − unbounded and bounded. Essentially, the unbounded model computes theoretical estimates of production quotas, while the bounded model computes practical estimates. To illustrate the applicability of the proposed models, a numerical real-world example is presented in OPEC member nations. Based on a preliminary analysis, only Algeria, Libya, Nigeria, and Venezuela were eligible for production allocations. The application of the unbounded model revealed all four nations were capable of maxing out their production quotas. For practical reasons, and in order to ensure market stability, the bounded model found out that only Libya could potentially receive a maximum allocation of 7.71%. This translates to an increase of 93 thousand barrels of oil per day for Libya. The bounded model not only averted excessive crude oil production but also curtailed hazardous waste associated with increased oil production, resulting in significant positive effects in both Libya and Venezuela. According to our findings, the unbounded model is appropriate for theoretical analysis, while the bounded model is suitable for regulatory bodies such as OPEC.

Numerical Modeling of Two-Phase Fluid Filtration for Carbonate Reservoir in Two-Dimensional Formulation

This work considers the isothermal process of incompressible viscous fluid filtration in an oil-saturated, fractured-porous reservoir. A study of the pressure and water saturation distribution process is carried out for a case in which a production well is put into operation. For this problem, i.e., a mathematical model in a two-dimensional formulation, a numerical method and a parallel algorithm are proposed. The mathematical model of two-phase filtration is written in accordance with the classical laws of continuum mechanics and Darcy’s law and also includes a function of fluid exchange between low-permeability pores and high-permeability natural fractures within the framework of the Warren–Root model. The numerical solution is based on the finite-difference method and a splitting scheme of physical processes and spatial coordinates. For a split system with respect to piezoconductivity, an implicit finite-difference scheme with fixed saturations is constructed, and with respect to saturation transfer, explicit and implicit difference schemes are constructed. For parallel implementation of the developed numerical approach, a method based on geometric parallelism is selected. Testing of the developed method is performed using the example of calculating liquid mass transfer for a wide range of parameters. To verify the model, the obtained calculated pressure curves are compared with field data recorded by a deep-well measuring device. The results allow for estimation of the distribution of reservoir pressure and water saturation depending on the permeability of the fracture set and the pore part. The obtained results allow for monitoring of well operations, reducing unexpected accident risks and optimizing the development system in order to increase oil production in fractured-porous reservoirs. Computational experiments confirm the efficiency of the developed numerical algorithm and its parallel implementation.

Field experiments and main understanding of shale oil hydraulic fracturing

To understand the key processes of hydraulic fracturing in shale oil reservoirs, such as artificial fracture initiation and extension, proppant transportation and settlement, and the influencing factors of post-fracture production, many hydraulic fracturing field tests have been conducted in the United States. Examples include the ConocoPhillips tests and the National Hydraulic Fracturing Experiment. The results have promoted the innovation and development of fracturing technology. A good correlation exists between lithological changes and the roughness of artificial fractures. Although numerous artificial cracks are created, the number that can provide oil and gas seepage is relatively small, determined by the effectiveness of these cracks. The settlement of proppants in actual geological formations involves factors such as geology, lithology, fractures, and stress. The pressure data indicate that when the reservoir pressure drops below the bubble point pressure, the decline in production sharply increases. The key variables affecting shale oil well production include the horizontal well position, well spacing, horizontal section length, and sand addition intensity. These technologies are suitable for the adaptive process of China’s terrestrial shale oil fracturing, promoting the development and rapid increase of shale oil production.

Research and Application of Compound Movable Gel Plugging Agent Suitable for Gasi Oilfield

Abstract In order to meet the water plugging requirements of high salinity reservoirs at different temperatures, we developed three kinds of movable gel plugging and regulating agent by using salt resistant polymer as the main agent, organic chromium and organic aldehyde as the cross-linking agent, supplemented by organic stabilizers and reinforcing agents. Namely, low, medium and high-temperature and high-salinity composite movable gel plugging and regulating agent, and the formulas are 0.4% YG-100 + 0.1% YG-107,0.4% YG-100 + 0.15% YG-107+0.8% YG-103,0.4% YG-100+0.15% YG-107+0.8% YG-103 respectively. The gelling performance, thermal stability and salt resistance of the composite movable gel are evaluated. The results showed the suitable temperature is 40~126 °C, and the salinity of formation water is 260000mg/L. Seven well groups were implemented on site, and the oil pressure in the water wells generally increased. Water channeling was controlled to a certain extent, and the comprehensive water content decreased from 90.5% to 85.1%, a decrease of 5.4%. The cumulative increase in oil production was 3164 tons, and a good oil increase effect was observed.

Three-dimensional physical experimental study on mechanisms and influencing factors of CO2 huff-n-puff and flooding process in shale reservoirs after fracturing

Carbon dioxide (CO2) capture and geological storage technology is a promising strategy for enhancing oil and gas production and mitigating climate change in unconventional formations. In shale reservoirs, production decline is rapid under volumetric fracturing development. Currently, CO2 injection and huff-n-puff techniques are cost-effective methods to boost shale oil recovery. However, traditional huff-n-puff techniques are limited in capturing reservoir heterogeneity and intricate fracture conditions. This study employed a three-dimensional physical experimental apparatus to explore CO₂ huff-n-puff dynamics across six distinct fracture patterns. By implementing a real-time monitoring system with multiple pressure points, the study elucidated the impacts of varying fracture penetration levels and spacing on dynamic pressure wave patterns, mobilization extent, and development outcomes during CO2 huff-n-puff. The results demonstrate that fractures substantially improve CO₂ huff-n-puff efficiency in shale reservoirs compared to a seamless model, with Model 6 achieving the highest recovery rate of 42.38%. As fracture penetration increases, CO₂ dynamic coverage expands. However, full penetration leads to preferential flow through fractures, reducing matrix contact and diminishing huff-n-puff efficiency. Reduced fracture spacing enlarges the well's control domain, amplifies CO2 huff-n-puff dynamic coverage area, and increases oil production and recovery rate. Conversely, decreasing fracture spacing accelerates oil and gas displacement rates, leading to higher economic expenses. The study concludes that 2/3 fracture penetration in five fractures offers the most efficient recovery method. For a 500 m horizontal well, optimal fracture spacing is recommended at 125 m, with a fracture length of 145.8 m for a well spacing of 417 m.

Technology Focus: Artificial Lift (October 2024)

Summer blockbuster season has passed, but it’s always nice to grab a bucket of popcorn and escape reality with a movie. Some movies even teach lessons—as in, sometimes it takes hard work and incremental improvements to advance. Chugging raw eggs, sprinting steps, and boxing meat slabs in epic training montages can be effective (Rocky), but so can optimization with computational flow dynamics. Paper IPTC 24243 shows that redesign of a jet pump sliding-sleeve coupling can considerably reduce pressure losses and increase throughput. The scientific method can even be exciting. Who doesn’t enjoy hypothesizing, experimenting, measuring, cleaning records, analyzing, and scaling up—especially if it pays off with a huge computer-generated explosion in the desert (Oppenheimer)? Paper SPE 218124 demonstrates the benefits of digitizing and analyzing operational data from electrical submersible pumps (ESPs) to improve run life and profitability. Paper OTC 34898 describes a comprehensive testing program to qualify load-bearing ESP deployment cable for corrosive conditions. Sometimes an overly precise plan draws us to the edge of our seats. The protagonist has recruited a crew of experts, rehearsed obsessively, ensured that every loose end has been tied, and yet some unknown still (temporarily) derails the vault raid (Ocean’s Eleven). Paper SPE 218028 attempts to bypass chance and minimize production interference by orchestrating a network of intermittently gas lifted wells. Is physics limiting what you can do? Then change the rules. You could move existence into a computer simulation (The Matrix) or perhaps start over with a novel material. Paper IPTC 23949 introduces fiber-reinforced thermoplastic sucker rods to accomplish more with less. Who doesn’t enjoy a quality sequel? There must be an infinite number of things that can be jumped with a car (The Fast and the Furious). Paper SPE 215010 analyzes failures of gas lift valves retrieved from subsea wells and could be considered a follow-up to paper OTC 30943, an artificial lift paper featured in 2021. Closure also can satisfy, even if it’s just the final act for a high school chemistry teacher with a side gig (Breaking Bad). With that in mind, it’s been an honor and a pleasure to pen the Artificial Lift Technology Focus page these past few years. I look forward to seeing who the directors cast next for this character. Recommended additional reading at OnePetro: www.onepetro.org. SPE 218124 Digitalizing the Management of Electric Submersible Pump Failures Through Failure Prevention and Post-Mortem Analysis Tools by Michael Ellsworth, Suncor Energy, et al. SPE 218028 Optimization of Gas-Injection Network Using Genetic Algorithm: A Solution for Intermittent Gas Lift Wells by Ankit Garg, Oil and Natural Gas Corporation, et al. IPTC 24243 Increasing Oil Production With Jet Pumps by Reducing Pressure Losses in the Jet Pump/Sliding Sleeve Coupling by J. Soria, Sertecpet, et al.

تصميم نظام غمر المياه لحقل الدفا النفطي

Currently, water-flooding is responsible for a big portion of world oil production. The vertical sweep efficiency and the areal coverage each of these requires careful sampling to get represented reservoir rock and fluid properties measures of reservoir heterogeneity, Economically, a pilot is a desirable tool for studying oil recovery performance on reservoir sample and then scaled up to yield the performance to be expected from field performance. Defa field was produced since 1968 with good oil flow rate reaching 200,000 BOPD but during the life of the field, the production decreased to 50,000 BOPD in 2001. So, this study was conducted to increase oil production by add some energy to the reservoir to increase average reservoir pressure and try to maintain it to initial pressure and to increase displacement and sweep efficiency. The water flooding design was implemented in sector model in the Defa field using five spots pattern. The study was performed by using Excel and Water Drive software to achieve a good water flooding design. When comparing the results obtained from two calculation methods, the minimum error was equal 0.03 percent and the maximum error was around 12 percent. So, the results were acceptable and the process was recommended to the Defa-field. Keywords: Water flooding; Software; Fractional Flow, Break through.

Assessing the feasibility of using municipal wastewater for aiding algal oil production: From a spatial coupling perspective

AbstractCompeting over limited freshwater resources has been a major challenge in sustaining algal oil production. To tackle this issue, municipal wastewater (MWW) is proposed to aid algal oil production but with unknown feasibility. This study aims to investigate the change in algal oil production in response to MWW distribution. Using California as a case, the result shows that the oil production is only 34% of what was proposed in a former study, with 29% to 74% of wastewater being derived to meet 4% to 9% of refinery water demand. There is no substantial increase in oil production beyond a MWW distribution distance longer than 24 km. The analytical framework developed in this study requires minimal data in climate and topographic inputs and can be applied at a global level to identify the most promising areas where algal oil production can be sustained by municipal wastewater.

Studying the Characteristics of Tank Oil Sludge

Oil sludge is one of the main pollutants generated by the oil industry. Due to serious pollution and increasing oil production, problems arise every year in the effective treatment of oil sludge. The current study examines the composition and physicochemical characteristics of oil sludge, as well as traditional and new methods for processing oil sludge. With the tightening of environmental protection requirements, oil sludge quality reduction, recycling, and harmless treatment technologies will become necessary in the future. The primary task was to determine the composition of tank oil sludge, separate it from mechanical impurities, and study the influence of ultrasonic treatment and subsequent atmospheric distillation on the extract. The separation of the concentrate and the composition of the tank oil sludge, using an extracted mixture of hexane and benzene, are considered. The use of modern SEM methods, elemental analysis, NMR analysis, IR, ultrasound, and GC–mass spectrometry made it possible to characterize the organic part of reservoir oil sludge and its distillation products. First, 300 g of tank oil sludge was preheated and mixed with 300 mL of solvent (hexane:benzene = 1:1). After mixing with the solvent, the result mixture was filtered. Then, it was placed in an ultrasonic bath and exposed to ultrasound at a frequency of 100 kHz for 30 min. After processing, it was extracted in a Soxhlet apparatus at a temperature of 65 °C to isolate the extract. The resulting extract was analyzed on a gas chromatograph with mass detection. The composition of the extract was as follows (in %): hexane—83.99; total hydrocarbon isomers—7.12; n-hydrocarbons—2.52; benzene—6.37%. At a temperature of 85 °C, the benzene yield was 65.85%. It has been established that the fractions obtained through the distillation of oil sludge at temperatures of 65–85 °C have improved dissolving capacity. It has also been shown that the use of these fractions promotes an increase in the content of hydrocarbon isomers by 12–13% in the extract composition.

Determinants of Petroleum Products Export from Niger

This paper aims to define the main determinants of petroleum products export from Niger in the light of the specificity of the country, in order to make recommendations to policy-makers for improving oil revenues. To carry out this work, we started by interviewing stakeholders in the Niger trade using an interview guide. This was followed by a literature review and exploration of previous empirical work on various studies devoted to the determinants of exports. Finally, statistical data from a number of sources were processed. The main results, derived from the estimation of the OLS gravity model, show that the factors that strongly influence Niger's exports are transport distance and its economic weight when put in relation to that of trading partners. The main recommendations towards policy-makers arising from our research are: the creation of a new refinery close to Burkina Faso and Mali, increased oil production and the ongoing improvement of road transport infrastructure.

Research for the Enhanced Oil Recovery Mechanism of Heavy Oil after Composite Huff and Puff Assisted by Edge-Bottom Water Displacement

Abstract In the late stage of exploiting heavy oil reservoirs with edge-bottom water, we are faced with problems such as high crude oil viscosity, channeling of bottom water, and rapid rise in water cut. To clarify the synergistic effect of N2, CO2, N2 foam, and viscosity reducer in water control and oil increase, and solve the problem of edge-bottom water rushing into production wells, one-dimensional sand-pack huff and puff experiments were carried out. First, the N2 foam huff and puff experiment evaluated the effect of N2 foam on controlling bottom water. Then the viscosity reducer assisted CO2 huff and puff experiment analyzed the synergistic viscosity reduction ability between the two to mobilize the remaining heavy oil. Next, the N2 foam-viscosity reducer-CO2 huff and puff experiment clarified the synergistic effect between the three. Finally, the N2 foam-viscosity reducer-CO2-N2 huff and puff experiment solved the problem of insufficient reservoir energy based on synergistic precipitation and oil increase. Experimental results show that N2 foam-viscosity reducer-CO2-N2 huff and puff is the optimal water control and oil increase solution. This solution can significantly reduce water production and increase oil production. In the one-dimensional sand-pack experiment, this technical solution reduced the water content by 68% and increased the recovery rate by 16.09%. The research results provide a reference for the development of exploitation technology schemes for similar edge-bottom water heavy oil reservoirs after entering high water cut.

Ocena skuteczności oczyszczania strefy przyodwiertowej

The article discusses issues related to methods of treatment of the bottomhole zone of wells and assessment of its effectiveness. Analyses of a large volume of field material have shown that the most effective treatments for oil fields at a late stage of operation include injection of solvents, the use of acid-containing micro-emulsions, acid treatment, and the use of foam systems. The study proposes a method for identifying the factors that have the greatest impact on the efficiency of geological and technical activities. This approach allows for the correct selection of wells for treatment and the evaluation of the effectiveness of the measures implemented, aiding in determining their potential for further use. For production wells selected for near-wellbore treatment, it is crucial to accurately assess the economic efficiency post-treatment. This requires evaluating changes in the permeability of the near-wellbore zone following treatment. Therefore, in these wells, the “pressure build-up curve” (PBC) is recorded both before and after treatment. The increase in current production due to acid treatment of the near-well zone is determined by comparing production levels before and after treatment. The overall increase in oil production is determined by comparing the well’s production curve prior to development with the actual curve following development. When treating the bottomhole zone, it is essential to consider the well as part of a larger system of interacting objects, where improving the characteristics of one object does not necessarily enhance the operation of the entire system. The effectiveness of treating the bottomhole zone with solvents is significantly influenced by factors such as the percentage of resins in the product, the specific gravity of oil before treatment, the specific gravity of the solvent, and the viscosity of the oil.

Optimization of Bacillus licheniformis’ nutrient system and oilfield trial for MEOR

Abstract The efficacy of microbial-enhanced oil recovery (MEOR) is contingent upon the performance of oil recovery functional bacteria. The optimization of the nutrient system for oil recovery functional bacteria can enhance their performance. In this study, the nutrient systems of the strains underwent screening and optimization procedures, utilizing single-factor combined with response surface methodology. Subsequently, field trials were conducted to assess the efficacy of MEOR. The results indicated that the carbon source in the nutrient system was sucrose, the nitrogen source was NaNO3, and the phosphorus source was a combination of KH2PO4 and Na2HPO4 (in a 1:1 ratio). The combination of the results from the single-factor experiments and the response surface experiment led to the following formulation for the strain F-T nutrient system (g/L): sucrose 10.0, NaNO3 2.0, KH2PO4 1.5, Na2HPO4 1.5, CaCl2 0.12, FeSO4 0.12, MgSO4·7H2O 0.2, Na2MoO4 0.08, yeast powder 1.0, and pH 7.2-7.5. The optimized F-T bacterium has the potential to spread oil up to a diameter of 40.50 mm. The results of the MEOR field trial indicated a 2.95 × 10 t increase in oil production, with a success rate of 83.87%. Following the implementation of MEOR, production levels were observed to decline to levels comparable to those observed prior to the intervention. This indicates that continued MEOR field applications may be necessary to further enhance crude oil recovery.

Towards in-depth profile control using s-MPG synergy with MSRG in fractured-vuggy carbonate reservoirs

In-depth profile control is a crucial technique employed to enhance oil recovery in fractured-vuggy carbonate reservoirs. However, it is a challenge to achieve in-depth profile control. In this paper, two types of organic gel systems, namely s-MPG and MSRG, tailored for fractured-vuggy reservoirs with 140 °C and 22 × 104 mg/L have been developed. FTIR was used to analyze the functional groups of s-MPG and MSRG. Additionally, the quality retention rates of s-MPG and MSRG were assessed using TG-DSC, yielding results of 92.85% and 92.65%, respectively. The dilution rates of s-MPG and MSRG are found to be 18.69% and 26.69%, respectively, demonstrating excellent compatibility and adaptability. The enhancement performance depends on the synergistic effect that the anti-dilution s-MPG effectively separates bottom water, while high-strength MSRG separates the oil layer. Moreover, the EOR performances of s-MPG synergy with MSRG in various types of fractured-vuggy carbonate models were also evaluated. The highest oil recovery of 12% is achieved in fracture network model. Laboratory results indicate that the synergistic combination of s-MPG and MSRG for water plugging in fractured-vuggy carbonate reservoirs results in a more effective enhancement of oil recovery compared to using a single gel system for plugging. Finally, the s-MPG synergy with MSRG has been applied in actual fractured-vuggy carbonate reservoirs. As expected, the water cut of typical well is reduced from 100% to 30% and the increased oil production is 1142 t totally. Therefore, this study presents a novel approach to achieving in-depth profile control by leveraging the synergistic effect of s-MPG with MSRG in fractured-vuggy carbonate reservoirs.

Optimizing gas lift for enhanced recovery in the Asmari formation: a case study of Abu Ghirab field in Southeastern Iraq

The gas lift technique applies gas bubble injection into the vertical wells to raise production. Gas and liquid rates, shifts in flow regimes, and system equilibrium influence this process. This study explores the efficient implementation of gas lift techniques to maximize production from the Asmari Formation in the Abu Ghirab Field, southeastern Iraq, using a continuous gas lift for maximum production rate by PIPESIM TM software. The results of the gas lift design for the four wells (AGCS-33, 26, 28, and 36) show that the Vogel method provided the best results for the gas lift design, and faults and facies distribution impact the gas lift injection and oil production rates. These will become evident with wells AGCS-33 and 36 as their proximity to faults will increase oil production rates with a gas injection rate limit of 7 MMSCF/d. Conversely, for wells 26 and 28, the limit will marginally rise, starting at 5 MMSCF/d. In addition, the effect of gas lift is clearly in the middle western of the crest, which shows an increasing percentage of oil production of 136.6% at minimum rate and 198.5% at maximum for the well AGCS-26, 89.7% and 105.7% for the well AGCS-36. Wellhead pressure has a significant impact on gas-lift performance, and improving gas-lift efficiency can be accomplished using an electric control valve. The feasibility of implementing gas lift in the Asmari Formation depends on the water cut, well location, and water saturation distribution within the Formation.

Optimization of Injection-Production Relationship of Offshore Unconsolidated Sandstone Reservoirs Based on Inter-well Connectivity

Abstract The dynamic heterogeneity of water drive sandstone reservoir in high water cut stage is strong, which leads to the differential enrichment and distribution of remaining oil. The adjustment of injection-production relationship can effectively guide the work of stabilizing oil and controlling water. Based on the principle of inter-well connectivity, this paper comprehensively considers the geological characteristics and development dynamics, and constructs the multi-layer reservoir joint well network inter-well connectivity model. By integrating the automatic history matching and the real-time injection-production optimization algorithms, the accurate inversion of connectivity parameters and real-time optimization prediction of production dynamics are realized. Field applications in the block X demonstrated that this method resulted in an annual increase in oil production of 16,000 cubic meters and a reduction in water cut by 0.87%, showing significant enhancement in oil recovery and water control. This method can be applied to guide the adjustment of the planar injection-production structure in similar reservoirs.

Some aspects of consıderable models of oıl and gas ındustry development

The article examines some assumptions and problems of the world economic theory, it is pointed out that these assumptions are based on the characteristics of the economic structure in different parts of the world where the distribution of world production and the global exchange of goods, services and other results of human activity take place, of course the oil and gas industry is not left out in this matter shown. Moreover, taking into account the importance of its impact on world politics, it has been pointed out that the field is one of the most relevant objects of economic analysis today. The characteristic features of modern globalization are given in the article. In such a situation, it was suggested that since the real scale of the application of methods that increase oil production in Azerbaijan is not able to prevent the deterioration of the structure of reserves, it will not be possible to make a big positive change in the exploitation of extractable reserves. The article also discusses the application of econometric models in economic research on the oil and gas industry. As a means of research and prediction of natural processes, the mathematical modeling method has been shown to be very widespread in oil and gas extraction. The observations made were summarized and it was shown that there is a systematic progress in the dynamics of the world economic system in the conditions of modern globalization, the main characteristic features of modern globalization were classified and given by the author, the creation of optimal conditions for the operation of the oil and gas industry as a result of the administrative and fiscal regulation of the state in the conditions of globalization was noted, and also the oil and gas industry some aspects of the theoretical models of the future development of the field have been studied and shown, taking into account its specific characteristics and in the context of the natural decrease of the volume of production. In the article, it was determined that one of the most important issues is the correct determination of the oil and gas reserves of the field, its calculation by separate reserve categories. Experience shows that it is very important to calculate these resources in different ways, to analyze the indicators of field development in detail, and to compare them with real indicators in order to implement one or another project indicators. The basis of these methods is the determination of reserves and their role in the technical-economic justification of the options for field development. This gives special relevance to such issues in the oil and gas industry and considers their constant improvement in the conditions of the market economy appropriate. The developed article is dedicated to the study of such issues.

Pengaruh Produksi Kelapa Sawit, Harga Minyak Kelapa Sawit Dunia, dan Emisi Karbon terhadap Volume Ekspor Minyak Kelapa Sawit Indonesia

Indonesia is the largest producer and exporter of palm oil in the world. Unfortunately, Indonesian palm oil exports are influenced by various factors, including environmental issues, which ultimately disrupt export benefits. This research aims to analyze the influence of production, world prices, and carbon emissions on the volume of Indonesian palm oil exports. The analytical method used is Two Stage Least Square (2SLS) with simultaneous supply and demand equations for Indonesian palm oil export volumes from 1991-2021. The research results show that the increase in palm oil plantation areas in Indonesia has positively contributed to the increase in world palm oil prices as demand also increases. Furthermore, the increase in world palm oil prices has encouraged Indonesia's exports to world markets. The increase in Indonesian palm oil production has encouraged an increased volume of exports to the world market. However, market appreciation for environmentally friendly palm oil has not contributed positively to the price and increase in palm oil export volume.

Integration between experimental investigation and numerical simulation of alkaline surfactant foam flooding in carbonate reservoirs

In Brazil, pre-salt carbonate reservoirs are largely responsible for the current increase in oil production. However, due to its peculiar characteristics, increasing oil recovery by water injection is not enough. Therefore, we seek to evaluate the recovery potential using chemical methods (cEOR). Among these, the Alkali Surfactant Foam (ASF) method appears with high potential, a variant of Alkali Surfactant Polymers (ASP) without the problems presented by it. Therefore, this work presents an innovative methodology, which seeks to evaluate the potential for recovery with ASF in carbonate reservoirs by integrating experimental characterization and recovery prediction using reservoir simulation. For this, phase behavior and adsorption analyses were carried out. The experimental results provided key parameters for the simulation, such as optimal salinity, surfactant adsorption, foam mobility reduction factors. The results are from two case studies of AS and ASF flooding, using a section of UNISIM-II benchmark, using a one-quarter of five-spot model. Having the modelling for these cEOR methods defined, an optimization process for each method was applied, allowing a reliable comparison among the methods and over a base case of water injection, seeking the maximization of the net present value (NPV). As a result, in the experimental part, a low interfacial tension (IFT) value of 0.003 mN/m was achieved with a surfactant adsorption reduction of 17.9% for an optimal setting among brine (NaCl), alkali (NaBO2.4H2O), and surfactant (BIO-TERGE AS 40). In the reservoir simulation part, using a fast genetic algorithm in the optimization process, a NPV of US$ 14.43 million higher than the base case (water injection) and a 4.5% increase in cumulative oil production for the ASF injection case were obtained. Considering the analyses of production curves (cumulative oil production and oil rate) and oil saturation maps, a considerable oil production anticipation was observed, which was the main reason for NPV improvement, proving the high potential for application of the ASF method in carbonate reservoirs.