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Russia
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- North America > United States > Texas (0.67)
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- Geology > Structural Geology > Tectonics > Plate Tectonics (1.00)
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- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin > Nadym-Pur-Taz Basin > Block V > Urengoyskoye Field > Achimov Formation (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin > Nadym-Pur-Taz Basin > Block IV > Urengoyskoye Field > Achimov Formation (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin > Nadym-Pur-Taz Basin > Block 5A > Urengoyskoye Field > Achimov Formation (0.99)
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Life Membership is both an award and a recognition of the fact that the person being honored has devoted all his life to the development of geophysics as a science and industry. This applies in full measure to Valery Zainulovich Garipov, one of the leading geophysicists of Russia, who recently became the first geophysicist to assume the high post of Deputy Minister in the Russian Ministry of Fuel and Energy. This appointment was preceded by a long path which began in the field and eventually led to the managerial level of Russia's largest geophysical enterprise one that was providing services to the richest part of the West Siberian oil- and gas-bearing province, including the Samotlor oil field, which is the gem of the world's oil industry. Valery was born 1 October 1944 in a small town on the banks of the great Volga River. The hardships of growing up right after World War II did not hinder Valery's education nor a natural thirst for adventure and discovery qualities without which a man will not make a real geophysicist.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Europe Government > Russia Government (0.58)
- Government > Regional Government > Asia Government > Russia Government (0.58)
- Information Technology > Knowledge Management (0.40)
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Feasibility of Foam-Enhanced Water-Gas Flooding for a Low-Permeability High-Fractured Carbonate Reservoir. Screening of Foaming Agent and Flooding Simulation
Derevyanko, V. K. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Bolotov, A. V. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Minkhanov, I. F. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Varfolomeev, M. A. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Usmanov, S. A. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Saifullin, E. R. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Egorov, A. N. (CJSC, Aloil, Bavly, Russian Federation) | Sudakov, V. A. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Zhanbossynova, S (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Sagirov, R. N. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation)
Abstract The carbonate reservoirs of the Alekseevskoye field (Russia, Republic of Tatarstan) are complicated by high heterogeneity and the presence of fractures, which make development difficult due to early water or gas breakthrough depending on the injected agent, as well as low of the productive horizon. To increase sweep efficiency and introduce fractured reservoirs into development, it is necessary to use gas enhanced oil recovery (EOR) technologies. To find the optimal technology in terms of technological complexity and efficiency, three technologies were compared: Water Injection (WI), Water-Alternating Gas (WAG), and Foam Assisted Water-Alternating Gas (FAWAG). Series of core-flooding tests were implemented under reservoir conditions on carbonate cores, and cores with artificial fractures, saturated with original reservoir fluids. For FAWAG method compatible with high-mineralization water surfactant was chosen. Total recovery factor for each test was calculated. It was equal to 33%, 76% and 53% respectively for WI, WAG and SWAG, on the original core models. Therefore, WAG and SWAG were chosen as most effective techniques to improve oil recovery for in comparison with CWI. In artificially fractured cores, the WAG method recovery rate was 40%; subsequent injection of a foaming active substance mixed with FAWAG formation water proved effective, increasing the oil recovery rate to 47% due to partial blockage of the fracture.
- Geology > Rock Type > Sedimentary Rock (0.46)
- Geology > Petroleum Play Type > Unconventional Play > Fractured Carbonate Reservoir Play (0.40)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.37)
- Europe > Russia > Volga Federal District > Bashkortostan > Alekseevskoye Field (0.99)
- Europe > Russia > Volga Federal District > Tatarstan > Volga Urals Basin > Romashkinskoye Field (0.94)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Fyodorovskoye Field (0.94)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Central Basin > Samotlorskoye Field (0.94)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (4 more...)
Abstract In this study we aim to evaluate carbon dioxide (CO2) hydrate sequestration in ultradeep marine settings, focusing on the Indian deepwater context. Major scientific issues and opportunities are highlighted, including methane (CH4) production through hydrate formation. Economic, regulatory, and technical aspects are explored comprehensively, considering Indian offshore zones. The research involves comparing deposition and potential reserves with CO2 hydrate formation characteristics, kinetic promoters, and potential factors for optimal design criteria. Factors affecting hydrate development, like porosity, salinity, and CO2 interactions, are discussed. Technological and environmental feasibility of hydrate-based carbon sequestration in subsea basins are established. Challenges include kinetics, diffusion, and economics for large-scale Indian basin testing. Chemical interactions, pore water saturation, and depositional environment effects are summarized. We also outline the research necessary for commercial CO2 hydrate storage in Indian basins, building upon previous work. This research contributes to CO2 sequestration and substantial CH4 production in deep marine environments.
- North America > United States (0.93)
- Asia > India > Andhra Pradesh > Bay of Bengal (0.28)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Tazovksy District > West Siberian Basin > South Kara/Yamal Basin > Messoyakhskoye Field (0.99)
- Asia > India > Andhra Pradesh > Bay of Bengal > Krishna-Godavari Basin (0.95)
- Asia > India > West Bengal > Bay of Bengal > Kerala Basin (0.94)
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Abstract A paper presents laboratory research conducted to evaluate technological properties of the nanoparticle-induced water shut-off agent and to assess its potential for gas recovery enhancement in geo-physically complicated reservoir conditions. The studied water shut-off agent is an inverse emulsion generated through the synergy of physico-chemical reactions between natural and artificial surfactants with silicon dioxide nanoparticles (NPs). Ultra-hydrophobicity and stability of the nanoparticle-based emulsion (nano-emulsion) conveys game-changing technological properties, resulting in a high performance of the water shut-off agent. Introduced in this paper research program was specifically developed to meet an inquiry of gas-condensate fields operator for an efficient physico-chemical or chemical water shut-off technology with zero secondary damage to reservoir. Therefore, the research program aimed to evaluate technological properties of the emulsion system with nanoparticles (ESN) in the tight sandstone formation conditions 8990 psi and 230ยฐF. Firstly, rheometric study and tests in an autoclave were conducted to measure rheology, stability, compatibility and floating property of the ESN water shut-off agent under heavier polymer-clay fluid. Secondly, core flooding tests were conducted on four sets of natural low-permeable sandstone core columns to assess reversibility feature of the ESN water shut-off agent and a threshold pressure of the gas-condensate breakthrough. Rheology of the investigated water shut-off agent characterized by the share thinning behavior, i.e., viscosity drops under rise of the share rate and the other way around. The pseudoplastic behavior of the ESN perfectly suits applications in gas wells because it improves processes of preparing and pumping the water shut-off fluid downhole, does not float under heavier process fluids and self-controllable in-situ. It was learned that the ESN is compatible with reservoir and process fluids, and stable at reservoir conditions 230ยฐF and 8990 psi. The ESN's blockage reversibility feature was confirmed in core floods. Overall, the research results confirmed innovative properties of the ESN water shut-off technology with its wide-range compatibility and high stability properties.
- North America > United States > Texas (0.46)
- North America > United States > Oklahoma (0.28)
- Asia > Indonesia > East Kalimantan (0.28)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District (0.28)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin > Nadym-Pur-Taz Basin > Achimov Formation (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin > Central Basin > Samburgskoye Field (0.99)
- Asia > Indonesia > East Kalimantan > Makassar Strait > Kutei Basin > Mahakam Block > Tunu Field (0.99)
- (3 more...)
Abstract Two major mature oilfields with multiple rigs (> 150) delivering hundreds of thousands of drilled metres annually, suffered from severe induced losses during their ongoing development and also redevelopment phases. These events of course significantly impacted the overall drilling performance, leading to substantial production issues and poor economics. Although the fundamental underlying nature of the losses varied; proven success in both cases was to significantly reduce the mud weight. Additionally, in both cases, the key to achieving this needed to be a solution using low-cost, minimal rig modification approaches while at the same time retaining the well productivity at equivalent levels. The applied solutions Team both identified and screened a number of approaches for achieving an effective MW reduction, and this process resulted in the proposal for the use of Hollow Glass Spheres (HGS) as the preferred methodology. A thorough study of the available literature and previous industry experience had demonstrated that HGS potentially met all of the requirements. In order to confirm the compatibility of the HGS, a series of laboratory tests were planned and performed; followed by a set of structured field trials, confirming the suitability of this technology. These results were then collated into a Basis of Design (BoD) for a drilling fluid system utilising HGS for drilling through target zones with abnormally low pore pressures, capturing lessons learned from all stages of their application. This paper will describe the details of the screening for the available solutions; as well as performing the feasibility study through laboratory tests and field trials. It will report on the phased approach taken for piloting the technology, describing the challenges and risks that were assessed, faced, and mitigated during both the testing and trialling stages. A review of the post-deployment lessons learned, techniques used, and approaches corrected during subsequent trial period(s) will be presented. A summary of the economic assumptions made, and their evolution will be covered; and then discussed with regards to technology upscaling and the further proposed developments and enhancements. The results of the HGS technical solution have greatly exceeded the original expectations and continuous improvement of the technology indicates much more to come. Discussions of the possible modifications and improvement to the HGS fluid system are ongoing and involve formulation, HGS type, logistics, strategy of HGS mud utilisation โฆ etc. The use of HGS on these two oilfields has been novel and has resulted in a generally greater interest and appetite within the industry for this area of application.
- North America > United States > Texas (1.00)
- Asia (1.00)
- Europe (0.93)
- Africa (0.67)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.46)
- Geology > Geological Subdiscipline > Geomechanics (0.34)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > West Central Graben > PL2244 > Block 21/27a > Pilot Field (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > West Central Graben > P2244 > Block 21/27a > Pilot Field (0.99)
- Asia > Russia > Far Eastern Federal District > Sakha Republic (Yakutia) > East Siberian Basin > Nepa-Botuoba Basin > Kurugunsky License Block > Srednebotuobinskoye Field (0.99)
- (2 more...)
Success Story of a Novel Completion Technology of Hybrid ESP-Gas Lift System Trial
Pramana, Harris (Saka Energi Indonesia) | Mario, Cio Cio (Saka Energi Indonesia) | Nugrahanto, Anang (Saka Energi Indonesia) | Hakim, Arief Lukman (Saka Energi Indonesia) | Eviany, Ameria (Saka Energi Indonesia) | Murtani, Anom Seto (Saka Energi Indonesia)
Abstract Selection of the most suitable production technologies; namely the type of lift to be used, to the design and implementation for well conditions has been one main responsibility of petroleum engineers. In an especially limited offshore field, not all methods are applicable as platform spaces, operating costs, and system reliability are needed to be considered. System reliability, for instance, entails well production profile to meet the acceptable operating range and to perform within specific run life to be rendered economic. Ujung Pangkah offshore field, located within Pangkah PSC Block off the northeastern coast of Java Island has been discovered in 1998 and carries on production since 2007. Having a typical gas cap with an oil rim, carbonate reservoir; Ujung Pangkah field has since been developed with commingle completion targeting both separated layers of oil zone and gas zone, utilizing only gas lift as its main artificial lift method. Concern for alternative lifting methods has arisen since 2019, due to the limitation of gas lift injection capacity that is no longer adequate for the current and future development wells at that time. Considering this challenge, Saka Energi Indonesia decided to perform ESP (Electrical Submersible Pump) trial on 2 wells. By design, the proposed completion will be of a hybrid ESP-Gas Lift, possessing both ESP components and typical gas lift components. ESP is decided to be the next artificial lift method to be applied because currently there are unused electric capacities from Gas Turbine Generators. To satisfy the acceptable range of ESP design criteria, both wells are equipped with AGH (Advanced Gas Handler)/Gas Separator, along with a gas vent line to produce this separated gas through the annulus. To fulfill the required dual-barrier-policy in offshore conditions, these wells are using specialized, feed-through-ESP hydraulic packer that enables ESP cable and gas vent line to be passed through. To ensure these wells reach the economic limit of ESP installation, this hybrid completion design is used; utilizing ESP as the main artificial lift and gas lift as a backup so that the well can still be produced with gas lift when ESP experiences failure. On the implementation side, the installation of ESP with backup gas lift on 2 wells has been successfully improving production, each up to 4.5 times and 1.5 times its previous oil rate pre-installation. Despite the first ESP being out of commission, ESP run life has been satisfied and the relative economic limit for the installation has been reached. In addition, the well can still be flowed with a backup gas lift system while waiting for pulling operation, which significantly extends the well run life and overall boosts the well's economic value.
- North America > United States > Texas (0.69)
- Asia > Indonesia > Java > East Java (0.25)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > South Kara/Yamal Basin > Novoportovskoye Field (0.99)
- Asia > Indonesia > Java > East Java > Pangkah PSC > Pangkah Block > Ujung Pangkah Field > Kujung Formation > Tuban Formation (0.99)
- Asia > Indonesia > Java > East Java > Pangkah PSC > Pangkah Block > Ujung Pangkah Field > Kujung Formation > Sidayu Formation (0.99)
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Development and Assisted Injection of Sub- And Supercritical Water by the Oil-Soluble Catalysts for the Intensification of Upgrading Process of the Bazhenov Oil Shale and Production of Synthetic Oil
Djimasbe, Richard (Kazan Federal University) | Varfolomeev, Mikhail A. (Kazan Federal University) | Galiullin, Eduard A. (Kazan Federal University) | Al-Muntaser, Ameen A. (Kazan Federal University) | Gareev, Bulat I. (Kazan Federal University) | Kadyrov, Rail I. (Kazan Federal University) | Suwaid, Muneer A. (Kazan Federal University) | Davletshin, Rustam R. (Kazan Federal University) | Prochukhan, Konstantin Yu. (Gazpromneft โ Technological Partnership LLC)
Abstract In this paper, an EOR technology was proposed, including a development of oil soluble catalytic compositions and their injection with sub- and supercritical water (sub- and SCW) for in-situ hydrothermal upgrading of oil shale and intensifies the generation of synthetic oil. The experiments were carried with the oil shale sample from the Bazhenov formation (Russia) with 9.13% of the total organic carbon (TOC) which 83% composed of kerogen, at the sub- and SCW conditions of 300-400ยฐC taking into account of the reservoir pressure โฅ 250 bars and with time (6-24h) in the presence and absence of catalysts. Combined methods have been used to characterize the catalysts, oil shale and assess the composition of the reaction products, are illustrated in the experimental section. Additionally, simulation software (Hysys v.12) was also used to calculate the heat load. In this study, the designation of the Kat-1 and Kat-2 refers to Nickel (Ni) based catalysts with the ยซvegetable oilยป and ยซtall oilยป as organic ligands, and the Kat-3 and Kat-4 refers to Iron (Fe) based catalysts with similar above organic ligands, respectively. The results of injection of sub- and SCW without catalyst showed that the maximum oil shale conversion reaches 52.46% at 350ยฐC and 24h. Consequently, the higher synthetic oil yields of 29.22%, 43.59% and 9.75 % have been obtained after the non-catalytic upgrading process at temperatures of 300ยฐC, 350ยฐC, 400ยฐC and time 24h, 6h and 6h, respectively. It has been established that an increase in reservoir pressure can lead to a proportional increase in yield of gas up to 2.74% at 400ยฐC. Injection of sub- and SCW with oil soluble catalysts at temperatures of 300ยฐC - 400 ยฐC improves the oil shale upgrading and it reveals that the maximum organic maters conversion of 76.67% at 350ยฐC was obtained using the Kat-1. Particularly, it has been found that due to high activity of nickel and considerable amount of ฯ bonds in the ligand the catalyst, the Kat-2 exhibits good performance for upgrading reactions and generate the synthetic oil. Consequently, at an identical temperature of 350ยฐC the yield of synthetic oil increased from 29.22% for the absence of a catalyst to 39.1% using the Kat-2. That means that the Kat-2 can increase more additionally 9.88% of synthetic oil also reducing 4 times the necessary time for the non-catalytic upgrading process. Moreover, at conditions of 350ยฐC and 24h, around 214.06 kg additional of synthetic oil can be produced from a ton organic using Kat-1. Overall, it found that the catalysts (Kat-2 and Kat-4) show appropriate ability for synthetic oil production, while the catalysts (Kat-1 and Kat-3) selectively improve the quality of synthetic oil and the gas yields. Thus, the reasons for good selectivity of Kat-2 and Kat-4 for the synthetic oil production is not only attributed to the metals (Ni and Fe) activities, but more to the types of the used ligand. The greater the number of pi bonds in the organic ligands of catalysts, the faster the catalyst is activated. We also observed that at a high temperature of 400ยฐC, a significant decrease in the synthetic oil yield is possible, due to fast decomposition of kerogen into gas and polymerization of intermediate products to coke. According to the results of GC the obtained synthetic oil at the optimal conditions of (350ยฐC, 6h, 24h and the Kat-3) most composed of gasoline - 6.95%, kerosene - 16.88%. It is revealed that the required amount of catalyst to upgrade a ton of Bazhenov organic potential is 13.42 kg, and the amount of sub- and SCW for injection is (8-10:1). After calculation, optimal energy load to reach optimal conversions (46.5% - 50.7%) is 2833 - 4250 kW/h. Thus, use of oil soluble catalysts for the synthetic oil production from the Bazhenov formation is potentially recommended, due to its ecological and has perspective for the exploitation of oil shale in Russia.
- Asia > Russia (1.00)
- North America > United States (0.93)
- Europe > Norway > Norwegian Sea (0.24)
- Geology > Rock Type > Sedimentary Rock > Organic-Rich Rock > Oil Shale (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Materials > Chemicals > Specialty Chemicals (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Asia > Russia > West Siberian Basin > Bazhenov Formation (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin (0.99)
New Generation of Modular Production Logging Array Tool that Enhances Flow Profiling in Hostile Environment and Complex Well Design
Tveritnev, A. (Adnoc Onshore, Abu Dhabi, UAE) | Almansoori, N. (Adnoc Onshore, Abu Dhabi, UAE) | Manea, A. (Adnoc Onshore, Abu Dhabi, UAE) | Benfriha, M. (Adnoc Onshore, Abu Dhabi, UAE) | Escobar, J. (Oilserv, Dubai, UAE) | Donzier, E. (Adnoc Onshore, Abu Dhabi, UAE) | Schoepf, V. (OpenField, Paris, France)
Abstract Production logging in horizontal wells is challenging by nature. The situation becomes even more complicated in depleted fields where three-phase flow is encountered frequently. Identifying water and gas entry points for shutting them off, assessing the smart completion effectiveness, and identifying poor performing zones for stimulation treatment are key applications for production logging diagnostics in horizontal holes. This paper highlights the effectiveness of the new generation production logging array tool in evaluating the flow profile in hostile logging environment that contains tar, sticky material, and debris, which represent a real challenge for the conventional production logging array tools. The conventional production logging array tools typically provide very reliable flow profiles whenever the downhole conditions are optimal. However, the presence of tar, sticky materials and debris in downhole conditions remains the main challenge for all the conventional PL array tools. A new PL array logging tool has been designed which allows to deploy in the hole a dense array of multi-physics micro-sensors. The instrument includes optical, electrical, mechanical, magnetic, acoustic, pressure, and temperature transducers achieving unprecedented performance for water โ oil โ gas โ solids identification as well as for the measurement of respective phases velocities. The micro-sensors inherit from MEMS (Micro_Electro_Mechanical_Devices) technology integrating within a tiny housing the sensing elements, analog and digital electronics, computing power and communication capabilities, having all the functions of a millimeter size downhole tool able to withstand the high pressure, high temperature, corrosive fluids of downhole environment. Beyond metrology this unique architecture also provides key advantages in terms of reliability and robustness, indeed, the array of independent micro-sensors offers redundancy and lowers the risk of global tool failure. Combining the new array tool with the spectral noise and pulsed neutron logs makes it possible to evaluate the completion integrity, flow behind the pipe and formation fluid saturation in a single trip. The case study will present the new technology and the results from the individual analysis that will demonstrate how they can be integrated to improve the understanding of the downhole panorama. The case study presented in the paper represents the first field deployment of the new generation production array tool in one of the most complicated operating environments in production wells where the conventional production logging array tool has failed to provide valid data. The new technology has overcome the hostile downhole environment and provided reliable PL data that successfully allows evaluating the downhole flow profile and identifying the exact oil and gas entry points accurately. The case study demonstrates how spectral noise and pulsed neutron data can successfully complement the downhole analyses obtained from specialized production logging sensors in these high-angle wells. The case study represents a horizontal well equipped with a smart completion. The logging objectives include production and saturation profiling, identifying the gas entry points, evaluation of flow behind casing, and diagnosis of leaks in the completion. The objectives have been achieved successfully by the new production array tool in combination with the spectral noise and pulsed neutron logging. The case study presented will demonstrate how operators can benefit from the effective use of the new generation of production logging array tool to define the production profile and identify fluid entry points in hostile environments that represents a challenge for the conventional production logging array tools. The improved understanding of the downhole fluid dynamics increases the probability of successful interventions, optimizing production efficiency, and overall improving field and reservoir economics.
New Approach for the Probabilistic Assessment of Organic Matter in the Source Rocks of the Bazhenov Formation for Estimation of Shale Hydrocarbons Resources
Topchii, M. (Rock Flow Dynamics, Serbia, Belgrade) | Bondarev, A. (Rock Flow Dynamics, Serbia, Belgrade) | Degterev, A. (Rock Flow Dynamics, Serbia, Belgrade)
Abstract Maps of organic matter distributions are an essential part of the basin modeling process for evaluation of conventional and unconventional hydrocarbon resources. This approach has become widespread for both assessment of the initial oil and gas generation potential and final assessment of the resource base. An important step in this method is pyrolysis of the core material, which is carried out in order to assess the geochemical parameters of source rocks. The data can be used to create maps of the distributions of geochemical parameters, such as the organic carbon content, the hydrogen index, the oxygen index, S1,S2,S3, TMax. The accepted assumption regarding the distribution of these parameters determines the entire modeling result and the final generation volumes. It is difficult to overestimate the impact of this process on the result of assessing the prospects for both traditional and shale hydrocarbons. However, a lot of uncertainty is associated with interpolation of parameters analyzed in wells into the interwell space because different interpolation methods give fundamentally different results. Deterministic interpolation methods are limited because of their nature and thus cannot be used for probabilistic estimation, so they are not considered in this work. There are two interpolation methods that can perform this process in a multivariate form: the geostatistical approach (SGS, GRFS) and the new Amazonas method, which integrates elements of artificial intellect. The stochastic approach to modeling has the undeniable advantages of estimating probabilities, and it includes uncertainties, which demonstrates the general idea more clearly. In most geology-related fields, the deterministic approach is gradually fading into the background, giving way to stochastic methods. This article considers a comparison of the SGS and Amazonas methods, their prerequisites and limitations, advantages and disadvantages using the example of a database of geochemical measurements of the Bazhenov source rock data. The results of modeling by both methods are shown in this work along with the issues of statistical stability of the results. The geostatistical approach in interpolation has been used for decades. It has a simple and understandable operating principle, but there are several fundamental limitations. These limitations are associated with the assumption of stationarity of the random variable under study. The proposed Amazonas method also offers a simple and understandable way to calculate the quantity being analyzed at each point in space. However, the latter does not have the limitations of the geostatistical approach. Besides, this method does not require the condition of stationarity for the quantity being analyzed and is also capable, depending on the settings, of reproducing both smooth and abrupt transitions.
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.85)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.82)