South Kara/Yamal Basin
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)
- (6 more...)
Enabling High Performance Multi-Lateral Wells: Current Technologies and Gaps
Shor, Roman J. (University of Calgary) | Mai, An (University of Calgary) | Manolakos, Athena E. (University of Calgary) | Sambrook, James (University of Calgary) | Trivedi, Ajesh (University of Calgary) | Hess, Scott (University of Calgary) | Arseniuk, Stephen (Clean Resource Innovation Network)
Abstract This paper presents the current state of the industry in multilateral wells (ML) and presents the key findings from a broad literature review and two knowledge sharing workshops hosted by the University of Calgary and the Clean Resource Innovation Network (CRIN) in late 2021 and early 2022. The technology to deliver ML wells is mature and has been demonstrated across thousands of wellbores around the world. Evaluation, characterization, and control of flows in ML wells is also possible using available technology, however, it is expensive and may be cost prohibitive. Modelling and optimization of flows from lateral legs may be done using existing reservoir simulators. However, some regulatory hurdles may remain, including accounting for production from different zones and licensing of legs. What generally limits the more widespread adoption of ML wells is the perception of elevated risk from decision makers, lack of familiarity with ML technologies, and the perceived costs of ML junctions and associated equipment and operations. By highlighting the technologies and successes, this paper aims to heighten awareness of ML technologies and further widen the adoption and implementation of ML wells.
- North America > United States (1.00)
- Europe (1.00)
- Asia > Middle East > Saudi Arabia > Eastern Province (0.28)
- North America > Canada > Alberta > Census Division No. 6 > Calgary Metropolitan Region > Calgary (0.25)
- Geology > Rock Type (0.94)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (0.48)
- Geology > Geological Subdiscipline > Geomechanics (0.46)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Exmouth Basin > PL WA-28-L > WA-28-L > Vincent Field > Lower Barrow Formation (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Exmouth Basin > PL WA-28-L > WA-271-P > Vincent Field > Lower Barrow Formation (0.99)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.99)
- (150 more...)
Abstract Characteristics of two brown oil fields in the South Turgai Basin Field pose challenges for field development. Oil rims bounded by a gas cap on one side and an aquifer on another side are present in both fields. These features coupled with poor rock properties make the development of these fields challenging. As a result, enhanced recovery techniques are necessary for the economic production of oil and gas. Accounting for high saturation pressure and weak aquifer reservoir pressure maintenance is considered critical for the oil rims, as these have been observed twofold reduction in reservoir pressure from the initial one. To account for such effects, previous producing wells were converted to gas and water injection wells. Gas flooding of the gas cap is performed using a crestal injection pattern and water injection into the gas-oil zone is used to create a water bank between the gas cap and oil rim. Moreover, waterflooding is launched by peripheral water injection with additional advantages attained from gravity segregation. Changes in oil and gas production have been observed as a result of pressure maintenance. First, the gas injection implemented in the wells located 1.5-3 km from the oil rim have prevented gas breakthrough in producers, despite the significant injection rates. High injection rates are a result of the governmental ban on flaring, since this prompts engineers to perform faster pressure recovery and target a higher volume of utilization. Second, crestal and edge water injection have different results in different parts of the fields. However, in some cases rim flooding have devastating effects as producers have been watered out. On one hand, the goal of decreasing the gas production was met, which happened earlier and was one of the biggest challenges facing the company. Consequently, gas-oil ratios decreased almost ten times than what they were previously. On the other hand, water-cut on many producers increased substantially, up to 90-95%, and in some areas top injectors even killed the down-dip producers. Thus, despite having solved one problem, another one emerged. Overall, crestal water injection (i.e., barrier waterflooding) is risky, and requires stricter regulation and management. Case studies from the South-Turgai Basin show that water injection in top structure of oil rims for enhanced oil recovery can lead to positive as well as negative results. Overall, the paper demonstrates the cause-and-effect relationship of the previously described impacts of such water injection and provides recommendations for proper waterflooding management in oil rims based on the success in other parts of the field.
- Europe (0.89)
- Asia > Malaysia (0.68)
- North America > United States > New Mexico (0.24)
- Geology > Structural Geology > Tectonics (0.48)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.47)
- Geology > Geological Subdiscipline > Stratigraphy (0.35)
- Oceania > Australia > Northern Territory > Amadeus Basin > Permit OL5 > Mereenie Field > Stairway Formation (0.99)
- Oceania > Australia > Northern Territory > Amadeus Basin > Permit OL5 > Mereenie Field > Pacoota Formation (0.99)
- Oceania > Australia > Northern Territory > Amadeus Basin > Permit OL5 > Mereenie Field > Horn Valley Formation (0.99)
- (10 more...)
Abstract Multilateral drilling technology has advanced to the point that it is now feasible to explore and extract resources from previously unprofitable reservoirs. It may also help to enhance field development management by allowing for more efficient fluid flow from the formation. Despite its various benefits, a multilateral well has some drawbacks and requires a significant amount of technical work to optimize drilling parameters and depth and well trajectory rise. The most critical issues occur for a fish-bone lateral when the turns are formed for each lateral. The measurements of WOB are complex and may be inaccurate, leading to torque and drag values that are miscalculated or misread. Currently, the soft-string model and the intermittent contact due to drillstring stiffness are used in torque and drag models. But they also have some limitations, such as the neglection of dimensional changes in the string components when assuming clearance of contact and the inability to fully model the irregularity of the actual well path when assuming complete contact throughout the wellbore. The suggested model is unique in its capacity to estimate precisely anticipate drillstring-wellbore contact forces and solve torque and drag parameters from surface to total depth using a conditional alternating use of the assumption that there is continuous contact of the wellbore wall and the drill string while turning to each lateral and clearance between the drill string and wellbore-wall when drilling through straight sections. The model shows how well path design calculation is done for multilateral wells. A non-constant curvature trajectory is built into the model. The unique procedure for calculating torque and drag in multi-lateral wells is explained with several actual field data tests.
- Africa > Nigeria (0.28)
- North America (0.28)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > South Kara/Yamal Basin > Yamburgskoye Field > Achimov Formation (0.99)
- Asia > Russia > Gulf of Ob > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > South Kara/Yamal Basin > Yamburgskoye Field > Achimov Formation (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin > Nadym-Pur-Taz Basin > Achimov Formation (0.98)
Sequence stratigraphic modeling of the Neocomian reservoir BG27 of the Minkhovskoye field (Russian)
Shakirova, A. N. (Tyumen Petroleum Research Center LLC) | Fishchenko, A. N. (Tyumen Petroleum Research Center LLC) | Shepelev, Ya. A. (Tyumen Petroleum Research Center LLC) | Snokhin, A. A. (Kynsko-Chaselskoye Neftegas LLC) | Makulov, R. I. (Kynsko-Chaselskoye Neftegas LLC) | Chernenko, D. V. (Rosneft Oil Company) | Lebedev, M. V. (Tyumen Petroleum Research Center LLC)
This article presents some results of the sequence-stratigraphic analysis performed at the Minkhovskoye field in connection with the discovery of gas deposits in the Lower Cretaceous clinoform complex (Akhskaya formation). The Minkhovskoye gas condensate field is located in Western Siberia on the northern shore of the Taz Bay within the Tazovsky District of the Yamalo-Nenets Autonomous District of the Tyumen region. In conformity with the accepted oil and gas geological zoning, it is located in the Messovsky oil and gas bearing area of the Gydan oil and gas region. The reduction in size and complexity of new objects in the Neocome of Western Siberia, together with the increase in the resolution of modern 3D seismic exploration, require further development of the clinoform concept. It follows from a number of modern works based on the modern model-independent methodology of sequence stratigraphy. The use of genetic sequencing for this purpose, firstly, makes it possible to fully utilize the vast experience gained during clinoform modeling, and secondly, it better corresponds to the practice of dividing the section into regional reservoirs and cap rocks. As a result of drilling N well in the Akhskaya formation of the Neocom of the Minkhovskoye field, two gas-saturated objects were identified, displayed on time sections in the form of two echelon-like intense negative anomalies. During the sequence-stratigraphic analysis, it was found that both objects are part of the Pym 2 genetic sequence. The lower one is the body of coastal-marine sandstones as part of the HST system tract, and the upper one is the body of coastal-marine sandstones as part of the lower parasequence of the FSST system tract. Judging by the forms of dynamic anomalies, the sand bodies in both cases were formed as a result of the progradation of the lobed (delta) type coast. The fact of the proven gas bearing capacity of these stratigraphic elements poses the task of their further mapping outside the Minkhovskoye seismic cube. The small area of the seismic cube has not yet made it possible to clarify the gas potential of submarine fan and shelf sand bodies in the upper parasequences of the FSST, as well as the gas potential of the shelf formation as part of the LST. This requires more extensive field studies.
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug (1.00)
- Asia > Russia > Ural Federal District > Tyumen Oblast > Tyumen (0.25)
- Geology > Geological Subdiscipline > Stratigraphy > Sequence Stratigraphy (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.45)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > South Kara/Yamal Basin > Yamburgskoye Field > Achimov Formation (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > Minkhovskoye Field (0.99)
- Asia > Russia > Gulf of Ob > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > South Kara/Yamal Basin > Yamburgskoye Field > Achimov Formation (0.99)
Adapting the Technology for the Construction of Taml-1 Level Multilateral Wells at the Novoportovskoye Field for Separate Production Accounting for Each Reservoir
Alekseev, Alexander (Gazpromneft-Zapolyarye LLC) | Samigullin, Linar (Gazpromneft-Yamal LLC) | Zimoglyad, Mikhail (Gazpromneft-Zapolyarye LLC) | Nagovitsyn, Vladimir (Gazpromneft-Zapolyarye LLC) | Katashov, Alexander (GEOSPLIT LLC) | Husein, Nadir (GEOSPLIT LLC) | Bolshakov, Viacheslav (GEOSPLIT LLC) | Bydzan, Andrei (GEOSPLIT LLC) | Vasechkin, Dmitriy (GEOSPLIT LLC)
Abstract Summary The Novoportovskoye field is characterised by a mainly complex geological structure and the presence of remaining reserves. The situation is further aggravated by significant oil reserves occurring right under massive gas caps. To make HC recovery profitable in such geological settings, new technologies are required. This paper provides an insight into the case of creating a multilateral well based on a new TAML-1 level completion solution utilising the properties of the impermeable top of one bed and the dynamic quantum PLT to measure production from each formation separately in accordance with existing regulations.
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > South Kara/Yamal Basin > Novoportovskoye Field (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
Increasing the Accuracy of Production Allocation from Each Reservoir: Integrating TAML-1 Well Construction Technology and the Dynamic Quantum PLT Method in the Field NP
Alekseev, Alexander (Gazpromneft-Zapolyarye LLC) | Samigullin, Linar (Gazpromneft-Yamal LLC) | Zimoglyad, Mikhail (Gazpromneft-Zapolyarye LLC) | Nagovitsyn, Vladimir (Gazpromneft-Zapolyarye LLC) | Bolshakov, Viacheslav (GEOSPLIT LLC) | Bydzan, Andrei (GEOSPLIT LLC) | Upadhye, Vishwajit (GEOSPLIT LLC) | Vasechkin, Dmitriy (GEOSPLIT LLC)
Abstract One of the largest oil fields on the Yamal Peninsula, the Field NP is characterised by complex geological settings. Massive gas caps pose significant complications to the extraction of large oil reserves occurring immediately below them. In such conditions, new approaches are required to achieve economically viable production. This involves well construction based on a fundamentally new configuration and the use of new technologies. When drilling wells that penetrate more than one target reservoir, the legislation requires performance monitoring and separate production allocation for each reservoir. The article dwells on the first case of separate production allocation in a multilateral well completed with the TAML-1 solution. The well penetrates two reservoirs with different porosity and permeability, using the dynamic quantum PLT technology. The well was drilled taking into account the properties of the impermeable top of one of the reservoirs.
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > South Kara/Yamal Basin > Novoportovskoye Field (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
Cost Engineering Software: Value Based Management of Oil and Gas Assets in All Investment Process Stages
Pashkevich, Lev (Gazpromneft STC, LLC) | Gordeeva, Daria (Gazpromneft STC, LLC) | Skudar, Oleg (Gazpromneft STC, LLC) | Kashafutdinova, Aliya (Gazpromneft STC, LLC) | Lyasovich, Denis (Gazpromneft-Razvitie, LLC) | Ulyaschenko, Vladislav (Gazpromneft-Razvitie, LLC)
Abstract This paper gives an overview of Gazprom Neft's strategic goals and describes how industry benchmarking helps in achieving them. In particular, we offer a general description of Gazprom Neft's cost management processes with a detailed focus on two of them: baseline cost and reserve estimate, and project cost monitoring and control. The digital landscape of cost engineering is also described, which is represented by three interrelated cost estimation tools, and a software product that allows you to manage capital expenditures at subsequent stages โ to monitor and control the cost of the project. The cost engineering software products are unique solutions for the industry, and their features are described in this paper.
- North America > United States (0.68)
- Asia > Russia > Ural Federal District > Tyumen Oblast (0.28)
- Asia > Russia > West Siberian Basin > Bazhenov Formation (0.94)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > South Kara/Yamal Basin > Novoportovskoye Field (0.89)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Tazovksy District > West Siberian Basin > South Kara/Yamal Basin > Messoyakhskoye Field (0.89)
Modelling of Electric Submersible Pump Work on Gas-Liquid Mixture by Machine Learning
Goridko, Kirill Alexandrovich (Gazpromneft-Khantos LLC, Gubkin University) | Shabonas, Arturas Rimo (Gubkin University) | Khabibullin, Rinat Alfredovich (Gubkin University) | Verbitsky, Vladimir Sergeevich (Gubkin University) | Gladkov, Andrey Valeryevich (Modeling Technologies Center)
Abstract Oil wells in Western Siberia usually placed on artificial drilling pads, forming well clusters up to 30 wells. The flow rate of each well in the cluster measured by an automatic measuring unit one by one. Often flow rate measurement requires several hours and flow rate of a single well can be measured once a week or less. This led to situation then events affecting well rate can be invisible between measurements. Identifying such events can be extremely useful in many cases, for example for wells with unstable behavior or transient regimes. The same challenges are also faced at distant green fields during their development, there the flow rates can be measured once a month with a mobile unit. The objective of this paper is to develop a virtual flowmeter model based on indirect high-frequency data of well operation and ESP. In Gubkin University, at the Petroleum Reservoir and Production Engineering Department, bench tests of ESP5-50 (118 radial stages) on gas-liquid mixture in a wide range of volumetric gas content (ฮฒin = 0-60%), intake pressure (Pin = 0.6-2.1 MPa) and pump shaft speed (n= 2400-3600 rpm) were performed. Three vibration sensors were installed on the unit: on the ESP, at the ESP discharge, on the pipeline, which simulates the wellhead production tree. During the bench tests were recorded series of pressures at the intake, discharge and along the pump length, series of current and power consumption, as well as vibrations with frequency several times per second. Based on the bench test results, we investigated the possibility of indirect determination of well operation parameters during artificial lift modelling by machine learning. As a result, the approaches to modelling taking into account various sets of parameters (features) have been studied: based on hydraulic parameters โ ESP intake and outlet pressure; based on hydraulic and electric parameters โ current and power consumption; based on hydraulic, electric and vibrating parameters. The analysis of data series allowed to define the boundaries of stable ESP operation, namely the transition to surging and pump starvation. The novelty of the work is: โmachine learning modeling of the gas-liquid mixture pumping process by electric submersible pump; โsolving both direct and inverse issues: as virtual liquid flowmeter as, virtual gas content flowmeter at the pump intake.
- Europe > United Kingdom > North Sea (0.46)
- Europe > Russia (0.46)
- Asia > Russia (0.46)
- (3 more...)
- Research Report > Experimental Study (0.67)
- Research Report > New Finding (0.46)
- South America > Brazil > Amazonas > Solimoes Basin > Urucu Field (0.99)
- North America > United States > Texas > Permian Basin > Delaware Basin > Thistle Field (0.99)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.99)
- (6 more...)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Downhole and wellsite flow metering (1.00)
- Production and Well Operations > Artificial Lift Systems > Electric submersible pumps (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)
Hierarchy of Integrated Models of Varying Detail to Solve Problems at Different Stages of Gas Condensate Projects Development
Varavva, Artem Igorevich (Gazpromneft STC) | Apasov, Renat Timergaleevich (Gazpromneft STC) | Badgutdinov, Ruslan Rustamovich (Gazpromneft STC) | Yamaletdinov, Ayrat Flyurovich (Gazpromneft STC) | Koryakin, Fedor Andreevich (Gazpromneft STC) | Sandalova, Ekaterina Evgenevna (Gazpromneft STC) | Samolovov, Dmitriy Alekseevich (Gazpromneft STC) | Bikbulatov, Salavat Miniahmetovich (PJSC Gazpromneft) | Nekhaev, Sergey Sergey (Gazpromneft-Razvitie)
Abstract This study makes an attempt to generalize the integrated modeling tools used by the authors in practice on the basis of the following criteria: the volume of the initial data, the integration mechanism, constraints and assumptions. Various types of integrated models are compared with each other, the need for their application is analyzed, they are connected at various stages of the project development and by the tasks solved at this stage. It also describes the challenges that the authors encountered when working with integrated models of various levels of detail, approaches to their solution, and the lessons learned.