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Collaborating Authors
SPE Annual Caspian Technical Conference and Exhibition
The Application of Formation Microimager and Wireline Formation Tester for Characterization of Coalbed Methane Reservoirs
Ramatullayev, Samat (Schlumberger) | Charupa, Mikhail (Schlumberger) | Mendybayev, Nurhat (Schlumberger) | Valiakhmetov, Rustem (Schlumberger) | Seilov, Yerlan (Schlumberger) | Kurmangaliyev, Daulet (Schlumberger) | Zhaldayev, Nurgali (JSC KazTransGas)
Abstract Logging wells drilled in coalbed methane reservoirs (CBM) is a common practice in the industry. As a rule of thumb, the logging suite comprised of standard methods is run to identify coal layers for subsequent degasification. However, given the increased popularity of the commercial methane production from CBM reservoirs, the petrophysical data from standard methods is not sufficient to evaluate the productivity of deposits and to assess the effectiveness of such projects. The permeability of the coal matrix is usually non-existent. The natural fractures are key controlling factor for gas migration and the performance of a CBM reservoirs depends largely on this parameter. In this study formation microimager was used to identify fractured intervals and based on these results the most promising intervals were selected for further testing. The well testing of low permeability formations can be extremely difficult due to the long build-up times to achieve different flow regimes. This step can be optimized by deploying wireline formation tester to estimate the permeability of the coal layers in open hole. Innovative extended spacing dual packer configuration of the wireline formation tester was deployed to selectively test coal layers ranging from 1 to 9 m deposited at shallow depths of 200-900 m. Fragile nature of the coal seams often resulted in washouts, which presented some challenges while inflating the packers to isolate the interval. Several cycles of fluid pumping were performed followed by pressure build-up periods until the radial flow regime was observed. Data processing and monitoring was carried out in real-time allowing to obtain high quality data and to optimize the operations. Data acquired by formation microimager was used to perform facial analysis to determine depositional environment and to further aid in mapping the coal layers and for future well placement considerations. The knowledge about the depositional environment allows to predict the regions where coal layers are formed confined by the flooding areas. The geological setting of the coal basin is made up of many coal layers of varying thickness deposited at depths of tens to hundreds of meters. The application of an advanced logging suite comprising of formation microimager and wireline formation tester allowed to selectively test the most promising coal layers. All the measurements were carried out in open hole at a drilling stage.
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
Wells’ Water Cut Measurements with Limitations of Testing Facilities in the Field
Shektebayeva, Raziya (KPO B.V.) | Bissakayev, Beibit (KPO B.V.) | Iraliyev, Amangali (KPO B.V.) | Mardanov, Almas (KPO B.V.) | Karatayev, Kanat (KPO B.V.) | Saada, Tamer (Royal Dutch Shell B.V.) | Madeley, Benjamin (Royal Dutch Shell B.V.) | Brancolini, Alberto (ENI) | Di Federico, Emanuele Giustino (ENI)
Abstract The objective of this article is to demonstrate recent results of a water cut measurement campaign in the Karachaganak oil and gas condensate field. Historical, inaccurate well water cut assessment was due to the limitations of well test facilities which led to uncertainty in short- and long-term production forecasts. Several approaches were conducted to eliminate uncertainties in water cut measurements and to evaluate and define adequate tools to use for future water cut analysis. The use of a mobile sampling flow loop installed at the well head, where turbulent multiphase flow is guaranteed, was a safe and reliable approach to measure the water cut of the producing low and high productivity wells. Sampling and analyzing the fluid at the well site at various operating well head pressures, frequently and for long periods of time, resulted in better understanding of water cut dependence with changes in drawdown. In addition to the use of sampling on site, the optical sensor (OS) technology was a trial tested on two wells along with the sampling flow loop to confirm the accuracy of the technology. The existing test separators were not designed to handle high water rates; moreover, due to the complexity of the produced hydrocarbon, multiphase flowmeters are not able to accurately measure the correct fluid phase contribution and, as a result, inaccurately estimate phase rates. The OS tool demonstrated accurate real-time water cut readings in the liquid phase, when compared with the flow loop samples, as long as a turbulent flow is guaranteed during measurement. Thus, this technology can be considered as an accurate tool for water cut measurements. The possibility of temporary and permanent installation of the optical sensor tool at the well site or test lines is under evaluation. The current field development focuses on improved recovery from the oil rim which is above a weak aquifer. In the historically developed areas of the field this aquifer is separated from the hydrocarbons by impermeable shale and therefore water production has been minimal. Current and future development requires the drilling of new wells in areas not protected by barriers; this has led to a number of recent wells having a relatively early water breakthrough. As a result of accurate water cut measurements, unallocated water in the field was well defined and led to better control of water producing wells to maintain stability of process facilities. This application confirmed the limitations and low level of accuracy of the existing well test separators. The successful campaign to improve water cut assessment was critical to update and re-evaluate production wells’ operating philosophy, reservoir management, and the future development strategy of the carbonate reservoir.
Maximum Reservoir Contact in Horizontal Wells Achieved with Multilayer Bed Boundary Detection Technology, Case Study from Kyzylorda Region
Tyran, Serik (JV Kazgermunai LLP) | Giesemann, Carl (JV Kazgermunai LLP) | Lukpanov, Akimzhan (JV Kazgermunai LLP) | Yermekov, Milat (JV Kazgermunai LLP) | Abzhanov, Nariman (JV Kazgermunai LLP) | Popov, Timofey (Schlumberger) | Evdokimova, Inna (Schlumberger) | Kurmangaliyev, Daulet (Schlumberger) | Makhambetov, Amangeldi (Schlumberger) | Kozhakhmetov, Mirat (Schlumberger) | Leontyev, Dmitry (Schlumberger)
Abstract In general, the objective of horizontal drilling is to maximize reservoir contact within the target interval to achieve the planned well performance in a thin layer or when drilling within a thin oil deposit, when the distance between the reservoir top and the oil-water contact (OWC) is short and there is a risk or borehole exit into the overlying formation or water-bearing zone. In horizontal drilling, there always exist risks associated with geological uncertainties. If the structural dip is different from expected, lateral thickness or reservoir property variations exist; if subseismic faults are present, the horizontal well, drilled as per plan, may not achieve sufficient reservoir contact. As a result, the well may underperform. Well placement (or geosteering) is used in horizontal wells to accomplish geological objectives. The well placement process is an interactive approach to well construction, combining technology and people to deliver optimally placed wellbores in a given geological setting to maximize production or injection performance. In Akshabulak field, southern Kazakhstan, multilayer bed boundary detection technology was applied for geosteering in two horizontal wells.
Abstract This paper describes workflow and results of an imaging project carried out on a seismic survey on the Karachaganak field, located on-shore Kazakhstan. The aim of the study is to gain a deep understanding of the reservoir architecture and reduce the uncertainties of the model. The business driver is to support the reservoir modeling for the next field development phase. Karachaganak is a mature oil and gas field, within the Pricaspian basin. The reservoir is an isolated heterogeneous carbonate bank, Permo-Carboniferous in age, ranging from four thousand to six thousand meters of depth. An evaporite layer serves as seal. The overburden is a clastic basin surrounded by four huge allochthonous salt diapirs. Given the high complexity of the area under investigation Reverse Time Migration was the most suitable algorithm for handling sharp velocity contrasts and to image sub-salt targets with a high accuracy and definition. A detailed interpretation of the reservoir and overburden horizons guided a geological based seismic velocity model building. Moreover, an innovative tomographic approach was able to both constrain seismic anisotropy and honor well markers simultaneously. The involvement of structural geologists is part of a regular procedure when embedding salt tectonics into the geophysical model is crucial. Indeed, the interpretation of the complex salt geometry was of paramount importance for the success of the project. Furthermore, leveraging on the available computational capacity, testing multiple scenarios in very short time allowed supporting the QA and QC processes, reducing the uncertainties in the most challenging areas. The final high-resolution image is consistent with well data, logs and cores, matching more than one thousand markers. A clear image of the inner reservoir reveals seismic stratigraphic features previously hidden. The combination of cutting-edge imaging technology, running on the best in class industrial supercomputer in the world, the expertise in geoscience and the commitment of a multidisciplinary team were the key factor to achieve these results. This work does not represent the current shared JV view on the subject.
- Geology > Structural Geology > Tectonics > Salt Tectonics (1.00)
- Geology > Rock Type (1.00)
- Geology > Geological Subdiscipline > Stratigraphy (1.00)
- Geophysics > Seismic Surveying > Seismic Processing > Seismic Migration (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (1.00)
New Approaches to Gas Condensate Field Development in Uzbekistan
Nazarov, Azizbek (Gazprom International) | Ten, Igor (JV UZLITI Engineering LLC) | Iskra, Artyom (JV UZLITI Engineering LLC) | Kryuchkova, Tatyana (Baker Hughes) | Golovatskiy, Yury (Baker Hughes) | Gryaznov, Andrey (Baker Hughes) | Ishimov, Ivan (Baker Hughes)
Abstract The paper considers new approaches to further development of mature gas-condensate fields, which are aimed at the maximum recovery of in-place reserves using the systems of horizontal wells. The gas-hydrodynamic simulations on the sector model of a depleted field were performed. Analysis of geological features of the fields of Uzbekistan is crucial to the planning of horizontal wells. As an example of how geological features are taken into account for effective further development of the fields, the reservoirs of Amudarya oil-and-gas basin are described. The questions of geosteering, well targeting along the formation and optimum completion of horizontal and multilateral wells, including with the use of inflow control devices, are addressed. Studies found the appropriateness of the operation of horizontal wells in comparison with vertical wells, which have several technological and economic advantages, such as the cost of such wells, simplified system of surface facilities, production rate as fraction of in-place gas reserves.
- North America > United States (1.00)
- Asia > Uzbekistan (0.87)
- Research Report > New Finding (0.88)
- Overview > Innovation (0.70)
- Asia > Uzbekistan > Amu-Darya Basin (0.99)
- Asia > China > Sichuan > Sichuan Basin > Moxi Block > Longwangmiao Formation (0.99)
- North America > United States > Louisiana > China Field (0.97)
- (3 more...)
Integrated Asset Modeling in West Siberia: A Case Study
Batalov, D. A. (LUKOIL – West Siberia LTD) | Yusupov, R. Y. (TPP Yamalneftegaz LUKOIL – West Siberia LTD) | Zykov, M. A. (TPP Yamalneftegaz LUKOIL – West Siberia LTD) | Zipir, V. G. (TPP Yamalneftegaz LUKOIL – West Siberia LTD) | Gontarev, D. P. (TPP Yamalneftegaz LUKOIL – West Siberia LTD) | Kukushkin, V.. (Nafta Expert LLC) | Bayguzov, R.. (Schlumberger) | Kraynova, E.. (Schlumberger) | Krivokorytova, M.. (Schlumberger) | Kharkovsky, A.. (Schlumberger)
Abstract As part of the LUKOIL smart-field project, the company develops and implements integrated modeling solutions in all its assets. LUKOIL-West Siberia, a subsidiary company that is LUKOIL's leading hydrocarbon producer, has chosen two pilot assets in Yamal to implement such technology solutions. This paper describes the creation and implementation of two integrated models, as well as model of gas transportation system from a group of fields located in the Yamal and the Krasnoyarsk region. Each integrated model includes the following components: reservoir – well – gathering system – processing. The results of the project implementation allowed to increase production performance and economic viability of the operator company and provided technology that enabled to forecast production rates with high accuracy.
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug (1.00)
- Asia > Russia > Siberian Federal District > Krasnoyarsk Krai > Krasnoyarsk (0.24)
- North America > United States > Arkansas > Smart Field (0.99)
- 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 > Bolshekhetskaya Depression > Pyakyakhinskoye Field (0.99)
- (3 more...)
- Information Technology > Software (0.48)
- Information Technology > Modeling & Simulation (0.32)
Abstract The Pierce Field in the UK Central North Sea has production potential significantly beyond the originally anticipated life. A Life Extension project was initiated to develop a scope of work to refurbish and upgrade the facilities, suitable for the revised field life. The initial plan was to perform a ‘full reset’ of the facilities to extend their operating life for a further 15 years, but this resulted in a very long production outage (14 months) with an intense period of capital spend in the short term. With the low oil price environment emerging at the same time, there was a need to identify an alternative approach which would significantly improve the field cashflow by phasing the Life Extension work. The revised approach was to develop a solution which had a more equitable balance of risk and value against cost, with production uptime a key value driver. Fundamental to this was building an understanding of the existing condition of the facilities and then developing a risk-based view of how they were likely to perform for the extended operational period. Focussing on the major risks and assessing them individually, ‘Decision-based’ roadmaps were then developed to plan the technical work required to enable decisions on mitigations to be made. A ‘Competitive Scoping’ mindset was used to ensure fit-for-purpose solutions were tailored to the specific risks. Starting from a ‘do-nothing’ perspective as the base-case, the incremental value of the mitigations was shown and compared to the level of risk reduction they brought. This then allowed decisions to be made on the optimum mitigation solution. In addition to the technical assessment of the individual risks, the execution strategy was also developed and concluded that a phased approach was achievable and would significantly improve cashflow from the asset. The result was a Life Extension ‘Programme’ rather than a single ‘Project’, where short, medium and long-term Life Extension scopes are scheduled according to their necessity. Each Life Extension scope will be managed as an individual sub-project and only executed ‘when required’. The revised strategy avoided an extended production outage in the short term, reduced total cost by circa 50%, and phased the spend over approximately 10 years.
- North America > United States > Pennsylvania > Erie County (0.62)
- North America > United States > Kansas > Butler County (0.62)
- North America > United States > Colorado > Weld County (0.62)
- Europe > United Kingdom > North Sea > Central North Sea (0.62)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 23/27 > op (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 23/22a > op (0.99)
- Production and Well Operations (1.00)
- Management > Risk Management and Decision-Making > Risk, uncertainty, and risk assessment (0.69)
- Management > Risk Management and Decision-Making > Decision-making processes (0.47)
- Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems > Mooring systems (0.46)
Successful Application of Different Managed Pressure Drilling Techniques in Russia: Identification of Challenges and Selection of the Optimum Approach
Borges, Sergio (Schlumberger) | Dobrokhleb, Pavel (Schlumberger) | Krivolapov, Dmitrii (Schlumberger) | Magda, Andrey (Schlumberger) | Soroka, Taras (Schlumberger) | Moiseenko, Ivan (Schlumberger)
Abstract The utilization of managed pressure drilling (MPD) techniques has grown significantly over the past three years in the Russian Federation. This paper describes the application of MPD surface back pressure technique using both single and multiphase drilling fluid systems in several oil and gas fields located in Russia. The Komi Republic is one of the biggest oil and gas producing areas in the European part of Russia and among Russia's top ten producers. Although the Yurkharovskoye oil and gas condensate field in Western Siberia is in the Tazov Peninsula, most of the field is situated offshore. That part of the field is developed from onshore locations using horizontal and extended reach development wells. In Eastern Siberia, the Yurubcheno-Tokhomskoye field is one of the biggest oilfields and presents highly fractured carbonates. Each field presents a different challenge and requires a specific approach. The application of MPD technology improved drilling performance and helped avoiding non-productive time. Utilization of reduced mud weight with MPD procedures using a semi-automated system helped reduce lost circulation and safely control background gas, thus avoiding well control events in the Lambeyshorkoye, Komandirshorkoye, and Alabushina fields. In the Yurkharovskoye field, a high-pressure, high-temperature well was successfully drilled to TD with application of a fully-automated MPD system, which facilitated precise control of bottomhole pressure during drilling, pumps-off events, and tripping operations. A multiphase MPD technique helped achieve planned TD in horizontal sections in Riphean formations of the Yurubcheno-Tokhomskoye field without catastrophic fluid losses. By injecting oil-base mud with nitrogen, the equivalent circulating density (ECD) was drastically reduced, lowering the volume of losses up to 5 times. In addition, near balance conditions increased the ROP while drilling. The first ever multi-lateral well drilled with multiphase MPD was successfully completed on Yurubcheno-Tokhomskoye field with minimal mud losses and no well control events. This paper will present details about how MPD technology makes it possible to drill formations with narrow mud weight windows where traditional approach was ineffective. The application of MPD technology helped successfully drill wells while reducing non-productive time, improving performance, and increasing the safety for personnel.
- Europe > Russia (1.00)
- Asia > Russia > Siberian Federal District > Krasnoyarsk Krai (1.00)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Gulf of Ob (0.67)
- Europe > Russia > Northwestern Federal District > Northwestern Federal District > Nenets Autonomous Okrug > Timan-Pechora Basin (0.99)
- Europe > Russia > Northwestern Federal District > Komi Republic > Nenets Autonomous Okrug > Timan-Pechora Basin (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Gulf of Ob > West Siberian Basin > South Kara/Yamal Basin > Yurkharovskoye Field (0.99)
- (22 more...)
Abstract This paper puts forward a first of its kind integration and transparency of Offshore Supply Vessels providing global positioning, fuel analysis and manifest details on the Tengiz mega project. Thus, enabling the project to have a faster execution time. The methods of research and design used a data-driven and action-based methodology. First, by the integration of disparate data, analysis on verification and then trend analysis to do a higher level of analytics. Machine learning techniques have been researched that when deployed will provide further enhancement to Caspian offshore planning work, that will significantly improve speed and efficiency on major capital projects.
- Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Tengiz Formation (0.99)
- Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Korolev Formation (0.99)
- Asia > Vietnam > South China Sea > Cuu Long Basin > Block 2 > Topaz Field (0.91)
- Asia > Vietnam > South China Sea > Cuu Long Basin > Block 1 > Topaz Field (0.91)
New Application of Old Data by Utilizing Long Duration Pressure Transient Tests and Permanent Downhole Gauges as High Value Assets for Improving Full Field Simulation Model with Additional Interference
Levchenko, Pavel (Tengizchevroil) | Iskakov, Elrad (Tengizchevroil) | Manakhayev, Ruslan (Tengizchevroil)
Abstract Accurate fracture characterization has a huge impact on production forecasts and evaluation of projects in Naturally Fractured Carbonate fields. Pulse/Interference Tests can give valuable information about fracture network by providing additional constraint for spatial fracture distribution between wells, which can be honored with application of geologically consistent trends (Levchenko et.al, 2017). However, operational execution of the Pulse/Interference tests is very challenging. Therefore, usually limited data are available from the planned surveillance jobs leaving large sections of the reservoir without information from Pulse/Interference tests, which could be used for calibration of the Fracture Model. Lack of Interference data can be resolved by examining already available measurements, which are generally used for other purposes. For example, the primary purpose of Pressure Transient Tests (PTTs) is obtaining kh and skin values, while Permanent Downhole Gauges (PDHG) are mostly utilized for recording reservoir pressure, which is used for conventional History Matching process. As it was found from this study, historical data from both PTTs and PDHGs could be a source of additional high value information of Interference tests occurring in the field, which nobody was aware of. Properly designed Pulse/Interference Tests are very difficult to execute in the field with high production deliverability requirements. However, examining historical data can reveal a lot of good quality Interference Tests, which were recorded and stored for decades, but not used for Fracture Model characterization. Additional information from Interference tests were applied to calibrate a full-field simulation model, significantly improving quality of the history match in comparison with previous models, and improved confidence in the production forecasts.
- Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Tengiz Formation (0.99)
- Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Korolev Formation (0.99)
- Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Korolev Field (0.99)