Day 1 Tue, November 15, 2022最新文献

{"title":"Examination of Cysteine, Glutamine and Isoleucine as Methane-Propane Gas Hydrate Kinetic Inhibitors","authors":"S. Longinos, D. Longinou, Mirlan Tuleugaliyev, M. Parlaktuna","doi":"10.2118/212055-ms","DOIUrl":"https://doi.org/10.2118/212055-ms","url":null,"abstract":"\u0000 Gas hydrates are recognized as a significant concern to the oil and gas flow assurance, as it generates pipelines blockages. In this research three alterative amino acids such as: glutamine, cysteine and isoleucine investigated if they work as kinetic inhibitors on methane-propane gas hydrate creation. The outcomes indicated that cysteine worked as inhibitor while isoleucine and glutamine worked as promoters (glutamine>isoleucine) for both hydrate formation and induction time. Experiments with glutamine and isoleucine have the highest value of hydrate productivity while the lowest value of hydrate productivity belongs to experiments with cysteine. From hydrodynamic behavior, radial flow experiments indicated better gas liquid contact compared to mixed flow experiments.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"17 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133700433","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Water Slug Simulation for Transient Multiphase Process Flow","authors":"Karlygash Kudaibergenova","doi":"10.2118/212056-ms","DOIUrl":"https://doi.org/10.2118/212056-ms","url":null,"abstract":"\u0000 Current paper represents water slug simulation details applied to realistic transient scenario of pigging gathering line that transfers oil and gas production to Tengiz Second Generation Plant.\u0000 Pigging as well as any dynamic multiphase flow creates a big challenge for receiving facility causing not only inlet separators level fluctuations, but also carrying a risk of process upset and plant facilities damage downstream due to water flooding. Big diameter long distance transportation lines significantly contribute to this risk. One of the triggers to start using OLGA dynamic simulation tool in TCO on constant basis, was water flooding event that damaged stabilizer internals. Modeling is able to predict water slug, considering conditions for water settling in the pipeline prior to transient event, and thus allows to prevent or minimize potential upset.\u0000 Several scenario results were reviewed and compared: one versus the other, including scenario with mitigation measures. Hilly underground profile and low flowrate through the line over certain amount of time appeared to be key factors in obtaining reasonable accumulated water content, whereas transient event speed defines how quickly this water will arrive as a slug. Recognizing processing facility handling limits, the control over impact could be maintained by increasing flowrate prior to event and/or reducing speed of change (pig velocity in this particular case). Besides getting realistic water slugs due to rigorous pipeline geometry and flow preconditions, slower actual historical pig movement (against earlier simulated with flat geometry) was finally explained.\u0000 Present research was done to demonstrate how accurate and detailed inputs and preconditions to the simulation case can improve software predicted water slugs and create safe guidelines to overcome negative consequences. This practically discovered simulation strategy established itself as credible over few years, is allowing to manage all dynamic operations safely.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"20 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132734243","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Study into the Optimal Placement of Horizontal MSHF Wells Relative to the Regional Stress in a West Siberian Field Using the Dynamic Marker-Based Production Profile Surveillance Technology","authors":"Dmitry Shestakov, Ilshat Badrtdinov, Marat Galiev, E. Malyavko, O. Gorbokonenko, Nikita Titovsky, A.Y. Bydzan, V. Bolshakov","doi":"10.2118/212052-ms","DOIUrl":"https://doi.org/10.2118/212052-ms","url":null,"abstract":"In the context of hard-to-recover hydrocarbon reserves, the role of timely and high-quality decision-making at the initial stage of project implementation is becoming even more crucial. Along with numerous variable parameters used in the development system design tasks, such as the producer/injector ratio, well spacing, well types, completion method, etc., one of the key factors is the selection of a placement pattern for horizontal wellbores of production wells relative to the regional stress.\u0000 Given the low-permeability reservoirs at the West Siberian fields, hydraulic fracturing (HF) is virtually the only method to manage the reservoirs in an efficient and economic manner. In this region, horizontal wells fitted with frac sleeves are drilled on a permanent basis, while an urgent task that affects the formation of an efficient drainage zone is to substantiate the location of the wellbore and of man-induced fractures that appear during multi-stage hydraulic fracturing (MSHF) relative to the maximum stresses.\u0000 In this paper, a study into the optimal placement of horizontal MSHF wells was made to ensure stable oil reserves recovery and increase the reservoir sweep efficiency in one of the areas of a large oil field. The key objective in this work was to determine the long-term reserves recovery efficiency in the wells with different orientations of their horizontal boreholes. In order to assess the inflow profile and composition in the horizontal wells, the dynamic marker-based production profile surveillance technology, which is one of the advanced industry standards in production logging, was applied [1].","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"55 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115782937","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Karachaganak Unified Action Team – KUAT Journey to Cross-Functional Collaboration","authors":"Arman Shantayev, Ulan Burkitov, Y. Volokitin, P. Dalmasso, A. Brancolini, M. Durekovic, Bolat Zhumabayev, Muratbek Aibazarov, Indira Kaziyeva, Beibit Bissakayev, Tanat Sultanov, Aidyn Kartamyssov, Alimzhan Adilbayev, Medet Shalabayev","doi":"10.2118/212053-ms","DOIUrl":"https://doi.org/10.2118/212053-ms","url":null,"abstract":"\u0000 Karachaganak is one of the world's largest oil and gas condensate fields in a deep heterogeneous carbonate reservoir with complex sour fluid system located in Western Kazakhstan. Karachaganak's estimated reserves are over 2.4 Bln bbls of condensate and 16 tcf of gas. The asset is co-operated by Shell and Eni through Karachaganak Petroleum Operating (KPO) b.v. Joint Venture.\u0000 KPO successfully deployed a new KUAT operating center with aim to maximize production and improve collaboration among key functional groups managing day-to-day field activities. Maximizing oil production means getting the most condensate liquids to surface at a given gas (or other) constraints by routing producer wells through the network to arrive at the lowest field GOR. Experience showed that the key success factor was to establish a collaboration between Subsurface and Production departments built upon common understanding of field data. Physical embodiment of this collaboration is the Karachaganak Unified Action Team – KUAT, which means \"power\" in Kazakh. This center was established in 2020 with physical placement of Petroleum Engineers together with Production, Process and Planning Engineers in one Operating Center at the field site.\u0000 The objectives of KUAT team include the following short-term integrated activities:\u0000 Daily well line-up optimization as per integrated limit diagram views Integrated activity planning – e.g. optimized start-up of the new wells and projects Well surveillance planning and execution – from reference plans, EBS and opportunity-based GOR management Flow assurance\u0000 KUAT team utilizes the industry standard digital solutions like PI and PI vision and Petex type of solvers as well as custom-made integrators like Data Integrator and Network Optimizer (DINO). In order to ensure that production is always maximized and potential downtime is minimized a robust understanding of the limit diagrams and well potentials is required. This information is provided by live integrated dashboards which include the real-time data from subsurface to export routes. The overall contribution from KUAT is estimated at ~7,000 BOPD or 3% of incremental field production.\u0000 This paper will cover the overview of KUAT journey from early concept development to current state explaining how this center operates today. Workflows and improvements are included in the discussion as well as challenges faced throughout the implementation of newly developed team within the organization","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"83 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132998238","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Dynamic Marker-Based Production Profile Surveillance in Horizontal and Multilateral Wells at the North Caspian Offshore Fields","authors":"Nadir Husein, E. Malyavko, R. Gazizov, A.Y. Bydzan, G. Kapranov, O. Gorbokonenko","doi":"10.2118/212059-ms","DOIUrl":"https://doi.org/10.2118/212059-ms","url":null,"abstract":"\u0000 During the well operation, it is important to monitor the current state of production on an ongoing basis, identify water or gas breakthroughs, analyze the reservoir depletion, and predict the well operation parameters. Production logging is a key stage of the efficient field development management.\u0000 This paper presents for the first time the results of the three-phase well surveillance on the North Caspian shelf. The specific features of the wells being studied are the presence of a motherbore and sidetracks as well as a multi-phase flow. The purpose of the studies was to acquire information on the actual inflow profile distribution and its composition, borehole contribution ratio, as well as water and gas breakthroughs in the boreholes of the wells in question based on the results of the long-term production surveillance using the innovative technology – markers for the oil, water and gas inflow.\u0000 The collected data improve the quality of technological decision-making, which further contributes to enhanced hydrocarbon recovery and reduces operating costs. The paper presents the accumulated experience in conducting the studies of horizontal and multilateral wells at the North Caspian offshore fields.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"37 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132282365","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Development of Gas Injection Strategy Optimized Under Subsurface Uncertainties in Naturally Fractured Karachaganak Reservoir","authors":"A. Al-Aruri, E. Iskakov, Han-Young Park","doi":"10.2118/212061-ms","DOIUrl":"https://doi.org/10.2118/212061-ms","url":null,"abstract":"\u0000 Optimization of injection strategy for the giant fractured gas-condensate Karachaganak field is the focus of this paper. Numerous development alternatives were assessed using DPDK simulation model coupled with surface network and further optimized by integration with streamline analysis. Advanced risk assessment enabled to mitigate risks associated with high uncertainties in fracture distributions and complex clinoforms within the development area. Optimization results are compared to alternative models from JV partners, considering geological, surface facilities and project uncertainties.\u0000 Four main workflows have been discussed; firstly, constructing DPDK model through integration of seismic, dynamic and petrophysical data to properly characterize fracture properties and reproduce reservoir connectivity. This process has been guided by advanced Design of Experiment to manage numerous uncertainties in history match and model selection. Secondly, coupling subsurface model with the surface network simulator and addressing re-routing challenges to generate realistic forecast and efficient production system. Thirdly, devising risk management workflow to ease decision making for the placement of future gas injectors, their completion designs and gauging benefits of different conformance control options. Lastly, finalizing injection strategy through using streamline-assisted optimization workflow under geological/surface facilities/project startup uncertainties.\u0000 Key observations are:\u0000 Alignment of stratigraphy and enhanced permeability/fracture distribution in DPDK and SPSK models helped in achieving comparable outcomes. Adoption of advanced risk analysis and early agreement with multi-disciplinary stakeholders on subsurface and surface uncertainty parameters for multiple available models enabled generating high-quality risk assessments. Benchmarking outcomes from standalone vs. coupled models is essential step to ensure reliability of coupled models. Re-routing of wells between processing units improves recovery. Agreement with Partners on the surface simulator (ENS) integrated with different subsurface simulators allows uninterrupted analysis of information. Automating dual connection due to frequent change in boundary processing conditions accelerates delivery of results. Frequent and well-prepared engagements with stakeholders improves communication and provides better management of expectations that helped meeting project deadlines. Confining gas injection inside outboard Clinoforms farther away from fractures is the most rewarding and safest option by minimizing gas breakthroughs and improving recovery.\u0000 This work was proposed by KPO, and conducted by Chevron Karachaganak support team, in part, on request of the Karachaganak Petroleum Operating Company. It was used by the Karachaganak Petroleum Operating Company and JV partnership along with alternative models to support decision-making for the next phase of phase development – the Karachagan","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"55 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121661666","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Application and Practice of Integrated Sand Control Technology in Shallow Heavy Oil Reservoirs in Kazakhstan","authors":"Y. Tao, Jianhua Chen, Jianjun Liu","doi":"10.2118/212097-ms","DOIUrl":"https://doi.org/10.2118/212097-ms","url":null,"abstract":"\u0000 Sand production of the oil well will cause a series of additional works, such as formation damage, underground machine ground equipment damage, workover operation and sand clearing construction of the storage and transportation system, which will increase the production cost and reduce the production rate, so it has always been a bottleneck problem facing the loose sandstone reservoir. The K oilfield is a typical shallow sandstone and heavy oil reservoir in Kazakhstan, which has been facing the problem of sand production. With the decline of the cumulative injection to production ratio and the decrease of the formation pressure, the problem of sand production shows a trend of increasing year by year, which has long-term negative impacts on development and production of the reservoir.\u0000 This paper systematically summarizes the technical exploration and practice of K oilfield in sand control, sand discharging and sand cleaning, and forms different supporting modes and methods for CHOPS, pre-completion sand control, sand prevention of production well and the well workover operation.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114299469","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Modeling Sand Transportation in Wells Under Different Multiphase Flow Conditions","authors":"Nursultan Bakyt, Hong-quan Zhang, Haiwen Zhu","doi":"10.2118/212093-ms","DOIUrl":"https://doi.org/10.2118/212093-ms","url":null,"abstract":"\u0000 Sand particles can be produced from reservoirs along with oil, water, and gas in the petroleum industry. Particles can cause serious flow assurance issues, blocking a fluid path and causing fluctuations in oil and gas production and transportation system. Studies have been conducted to identify critical particle transport velocity in horizontal stratified flow. However, very little has been done to identify critical particle transport velocity for different inclination angles and flow patterns in the oil and gas production system. In this paper, two mechanistic and three empirical models are selected, modified, developed, and presented for stratified, slug, bubbly, dispersed bubble, and annular flow patterns. A model for particle transport in gas production well is also presented. Zhang et al. (2003) unified gas-liquid pipe flow model is applied to cover all inclination angles to determine flow pattern, liquid holdup, and other flow conditions.\u0000 Particle transport in a production system is controlled by many parameters like fluid properties (liquid and gas densities, liquid and gas viscosities), sand particle properties (density, size, concentration, angle of repose, sphericity), well geometry (pipe diameter, roughness and inclination angle), and fluid flow (flow pattern, superficial liquid and gas velocities, liquid holdup, water cut). The effect of each parameter on the critical particle transport velocity is analyzed to find the most important ones. The evaluations are validated by comparing with the previous work and experiments. However, this model validation part is not covered in this paper.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125789980","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A Set of Options for Stimulation of Wells","authors":"A. A. Isaev, R. Takhautdinov, V. I. Malykhin, A. A. Sharifullin, M. M. Aliev","doi":"10.2118/212098-ms","DOIUrl":"https://doi.org/10.2118/212098-ms","url":null,"abstract":"\u0000 The most effective well interventions employed by Shehsmaoil Management Company LLC (Republic of Tatarstan, Russia) are the following [1-4]:\u0000 – hydraulic fracturing (HF), – forced gas extraction unit from a wellbore annulus.\u0000 The article addresses the issues of increasing recoverable reserves of oil, oil recovery factor, speeding up development, improving the profitability of deposits and fields (with carbonate deposits) as a whole through the introduction of proppant fracturing technology (PHF), multistage fracturing in wells with horizontal endings, drilling a compact grid of wells with subsequent fracturing. It is indicated that optimization of PHF (transition to hybrid hydraulic fracturing) by combining low-viscosity and cross-linked fluids depending on the performance during test injections made it possible to stabilize product's water cut, increase well productivity in terms of oil and stabilize oil recovery reduction rate.\u0000 All relevant operations are implemented by three functioning hydraulic fracturing fleets operated that uses the equipment mounted on all-terrain chassis. The paper reviews and summarizes the application results of various fracturing fluid systems: borate-crosslinked guar fluids, Bioxan modified natural polysaccharide, fluids based on fresh water or viscoelastic surfactants, guar-free low-viscosity and high-viscosity water-based polymer systems, synthetic gelling agent. All the described systems feature the required sand trapping properties, so it is the price of the systems that determines the best choice.\u0000 The article considers a portable set of equipment for forced extraction of gas from the wellbore annulus and its subsequent pumping into the oil pipeline by means of gas extraction sets of the KOGS type.\u0000 In the conditions of shallow fields with hard-to-recover reserves the Company specialists encounter the challenge of increasing the profitability of development. The main reserves of the fields under consideration are confined to carbonate targets, and the reserves of deposits of the Kizelovsky gorizont of the Tournaisian stage occupy a considerable place by their quantity. Development of this object is mainly complicated by the following factors: complex geological structure, viscous, heavy and resinous oil, low reservoir temperatures and pressures. For the reasons of low efficiency of classical development systems, systems of reservoir pressure increase, it is necessary to develop, test, introduce new methods of intensification, new elements of development - compaction of well grid, horizontal wells (HW) with the following multistage fracturing. The fields considered in the article are tectonically controlled by the Western slope of South Tatar arch and Eastern edge of Melekesskaya depression, territorially located in Tatarstan.","PeriodicalId":394241,"journal":{"name":"Day 1 Tue, November 15, 2022","volume":"19 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133003725","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}