Vol 7, No 1 (2025)

Background: The foundation for field development and the justification of oil recovery factors relyies on a precise geological model. The reliability of this geological model depends on the specific characteristics of the deposit structure. Challenges in constructing the model arise from the significant lithological and facies variability of rocks. This article examines the structural features of the Yu-IX horizon of the Middle Jurassic Bajocian Stage of the Burmasha oilfield, incorporating new seismic data using the 3D common depth point (3D CDP) method and well drilling data.

Aim: Presentation of a new geological model of the productive strata of the Burmasha oilfield based on the 3D CDP and drilling data, and determination of sedimentation conditions during the deposit formation.

Materials and methods: The study applies new data from the interpretation of the 3D CDP seismic survey. It analizes cross slices of the eXchroma attributes, spectral decomposition (SD), RMC and Vp/Vs within the productive horizon, as well as drilling data from the entire well stock of the field.

Results: The study results in the clarification of the boundaries of paleorusic deposits of the productive horizon and the determination of the sedimentation conditions in the productive strata. The data obtained show the importance of using modern exploration methods to provide a reliable geological model.

Conclusion: The findings of this study provide a more accurate representation of the geological structure, estimate the reserves of hydrocarbon raw materials (hereinafter HRM), and enable further planning of a efficient system for the field development. All this will enhance the efficiency of hydrocarbon production, mitigate the risk of penetrating the clay-rich sections, and enable strategically position of new wells in areas with beneficial reservoir properties.

Background: Since commencement of the operations at the Amangeldу gas condensate field, fully separating the moisture from the condensate has proven challenging. Achieving complete moisture separation in gas condensate is essential for enhancing the technological process and preventing potential complications. To address this issue, current methods involve lowering the hydrate formation temperature in the internal gas transport pipes across various gas and gas condensate fields. In gas treatment, antihydrate inhibitors such as methanol and diethylene glycol are commonly used in flowlines, reservoirs, and various equipment. If precautions are not taken to prevent hydrate formation (inhibitors) during the production and treatment of oil, several challenges may occur. For instance, during production, the internal diameter of the flowline can diminish due to the of hydrate buildup, and in some cases, gas condensate may not flow properly due to the hydrate blockages. This can result in a reduction in the amount of products produced, or may lead to a complete shutdown of the well. Consequently, a portion of the produced products, such as gas and condensate, is sent to a flare. These production complications negatively affect the overall performance of the field.

Aim: To develop measures to prevent hydrate formation and address complications at the Amangeldу gas condensate field that may arise during production and treatment of well effluents and the transportation of these products through pipelines and plant equipment to the integrated gas treatment unit.

Materials and methods: To prevent the formation of hydrate from wells to the Central Processing Facility (CPF), it is proposed to introduce methanol (technical grade) into the gas stream using inhibitor dosing pumps. Additionally, diethylene glycol will be sprayed as a mist into the gas stream as it passes through the CPF equipment.

Results: When producing gas condensate from wells without the use of methanol and diethylene glycol, the volume of gas directed to the flare and vent stack amounts to 4.95 million m3, with a total cost of 128.7 million tenge. In contrast, if hydrate inhibitors are employed, it will be necessary to procure 180 tons and 10 tonnes of diethylene glycol, resulting total expenditure of 28 million tenge. Utilizing these hydration inhibitors has led to an estimated product savings of 100.7 million tonnes.

Conclusion: To date, the operation at the Amangelу gas condensate field have not fully addressed the separation of moisture from the gas. As a result, several issues arise during the winter month: excess moisture leads to the formation of hydrate blockage in the piplines, obstructing the flow of gas and condensate. To mitigate this issue, we propose implementing measures that involve adding methanol (methanol technical grade) to the gas stream with metering pumps of inhibitors, and diethylene glycol sprayed as a mist into the gas stream passing through the CPF equipment. These measures could also be widely applied to other gas condensate fields. By adopting these measures, it is possible not only to alleviate operational challenges but also to reduce the volume gas and condensate that is wasted and flared.

Background: Determining the mass flow rate and dryness of thermal agent at the wellhead of steam injection wells is a critical process in the operation, optimization and effective control of its injection regulation. In view of the fact that modern steam flow rate determination instruments based on measurement of variable flow of two-phase medium (steam and water), having a methodological error of more than 10%, cannot provide the necessary accuracy and reliability of measurements, there was a need to develop a calculation variant with the use of specialized software that would allow to correctly solve the problem of determining the degree of steam dryness.

Aim: Development of an algorithm for calculation of mass flow rate and dryness of thermal agent at the wellhead of steam injection wells of the K field using specialized software.

Materials and methods: Two-phase flow of steam and water in wells is a complex process, where it is important to take into account both physical properties of the medium (temperature, pressure, viscosity) and hydraulic characteristics of the system (resistance of pipelines, pressure losses). Mathematical simulation of two-phase flow “steam – water” was performed in a specialized software package by building a ground model and conducting hydraulic calculations. This specialized software complex allowed to build a mathematical model taking into account these parameters, which provides high accuracy and reliability of calculations.

Results: An algorithm for calculating the mass flow rate and dryness of the thermal agent at the wellhead of steam injection wells of the K field based on the model of the onshore steam injection system through the use of a specialized software package has been developed. Simulation allows predicting and optimizing the operation of steam injection wells. By changing model parameters (e.g., production mode, coolant parameters), the impact on well performance and system efficiency can be evaluated.

Conclusion: To date, it has not been possible to select equipment that allows correct registration of the two-phase flow of steam-heat agent injected into wells, which is typical for the conditions of the K field. The algorithm developed with the help of a specialized software package is applicable in the formation of technical solutions to improve the efficiency of control of steam injection process regulation.

Background: This article examines the importance of reliable PVT data on reservoir fluid properties for calculating oil and gas reserves, as well as for making informed decisions during the design and operation of fields, using the example of the suprasalt complex of the Uaz structure. This structure is divided by tectonic faults into three flanks: southwestern, southern, and northeastern. The southern flank is separated by a feathering fault into two fields – western (Uaz Main) and eastern (Uaz East). The northeastern flank contains the Uaz North field. Over different years, PVT studies and geochemical studies (fingerprinting) have been conducted at these three fields to confirm the data.

Aim: The purpose of this work is to evaluate data from PVT studies and geochemical fingerprinting, to identify differences and similarities in reservoir fluid properties for three fields: Uaz Main, Uaz East and Uaz North.

Materials and methods: The study used data from PVT surveys conducted in different years at the three fields, as well as geochemical studies to confirm the data obtained, including the fingerprinting method. All data were used to analyze differences and similarities in fluid characteristics.

Results: The results of the analysis allowed us to identify differences and similarities in reservoir fluid properties, which contributes to more accurate data interpretation and improved field development management.

Conclusion: The obtained PVT property data and geochemical study results contribute to improving the accuracy of reserve estimation and enhancing the efficiency of field development management using the example of the Uaz structure.

Background: Research conducted by KMG Engineering LLP on the organization and mainenance of oilfield equipment (OFE) in the oil and gas production units (hereinafter referred to as OGPU) has revealed substantial opportunities to enhance equipment reliability through organizational improvements.

Aim: The software module is aimed to reduce oil production costs and increase the on-stream factor by minimizing oil losses caused by downtime of OGPU oilfield equipment and reducing costs of its repair as well as optimally distributing the workload among OGPU employees.

Materials and methods: The study analyzes statistical data over a specific period, focusing on key indicators related to labor costs, labor productivity, and other aspects. For the analysis, modern methods to calculate time standards and data processing software were applied. The study adhered to current industry standards and guidelines, including labor safety regulations, requirements for maintaining oilfield equipment, and best practices for managing production processes. The approaches used in this study ensure the objectivity and representativeness of the results obtained.

Results: Checklists and standard operating sheets have been developed. Instructional videos have been created on the basic tasks of the OGPU employees. Additionally, special software for mobile devices (smartphone, tablet) and a web version of software integrated with the ABAI Information System have been developed.

Conclusion: The implementation of the Digital Assistant (OGPU) module in the oil and gas industry marks a significant milestone towards digitalization of OFE maintenance process, greatly enhancing both efficiency and safety. Standardizating and unifying processes through mobile and web applications enhance efficiency and accuracy in information transfer, reduces errors and speeds up decision-making. Optimizing staff workload and increasing the quality of data collection not only leads to cost reduction, but also improves working environment. The project can be potentially scaled up and implemented in other divisions of the subsidiaries and affiliates of NC KazMunayGas JSC. This expamsion could open up new opportunities to increase operational efficiency in the industry.

The purpose of the article is to analyze the opportunities and challenges faced by Joint Ventures (JVs) in the context of the SHIVA world and to assess their relevance and applicability to Kazakhstan. The study aims to identify key factors for JV success in the context of modern global challenges and uncertainties.

The following research methods were used in the article: literature review – analysis of existing studies and theoretical models of JVs and the SHIVA concept; comparative analysis – study of global and regional JV practices to identify common patterns and differences; case study – analysis of successful JVs in various industries and their applicability to Kazakhstan. The study reveals that JVs offer significant strategic benefits, including access to novel technologies, resource optimization, and market expansion. Nevertheless, challenges such as cultural disparities, governance intricacies, and knowledge safeguarding persist as critical obstacles. An analysis of global JV instances, including Tesla’s partnerships and collaborations in China’s automotive industry, underscores the significance of trust, strategic coherence, and flexible governance structures. Furthermore, in the energy industry, particularly the oil and gas sector, JVs contribute significantly to risk-sharing, technological advancement, and regulatory conformity. The integration of AI and big data analytics into energy JVs enhances predictive maintenance, reservoir modeling, supply chain visibility, and contract administration. JVs continue to be a crucial strategy for promoting global business expansion, but their success hinges on meticulous planning, effective management, and the capacity to adapt to swiftly evolving market circumstances. Digital transformation, especially through the use of artificial intelligence (AI) and big data analytics, is revolutionizing JV operations by improving efficiency and mitigating risks. Future JV models must focus on strategic adaptability, sustainable governance mechanisms, and digital integration in order to remain competitive in the hyper-connected global economy. In particular, the energy sector is undergoing a transformation through digitalization and AI-powered solutions, enabling companies to navigate operational intricacies, enhance decision-making processes, and achieve long-term sustainability in their JVs.