This paper presents a study, illustrating results of effective cooperation between the Operator Company of the Kuyumbinskoye field, Drilling Contractor, and Service Company involved in the construction of the horizontal well using the technology of Managed Pressure Drilling (MPD). This article also describes the challenges encountered and successfully implemented engineering solutions permitting to meet these challenges. The main challenge in the Kuyumbinskoye field is the high risk of mud losses in the productive interval. The complex geological conditions as well as the anisotropy of the productive horizon complicate the prediction of catastrophic mud losses zones location. Approximately 50% of the wells were not drilled to the planned depths. To solve this problem, in 2017 a pilot project using MPD technology was initiated. The main goals to be reached by the implementation of this technology were drilling efficiency improvement, risk management, and well construction cost efficiency improvement. In order to achieve the goals, equipment was selected, a comprehensive well construction program was developed and detailed work plans were prepared. As a result of thorough planning and close cooperation at all work stages; the multidisciplinary team successfully completed the construction of 11 wells with an average extension of a horizontal interval of approximately 1000 m, drastically reducing fluid losses and associated non-productive time (NPT). By eliminating NPT and thus increasing the effective rate of penetration (ROP) during one of the wells, the drilling time of the lateral section was reduced to seven days, comparing to an average drilling time of the horizontal section of approximately 20-25 days (with conventional drilling). In addition, the average losses of drilling fluid per well were decreased by more than 1000 m3. The application of specially developed technological solutions during this pilot project not only ensured the attainment of target depths and geological objectives but also confirmed the potential of producing crude oil while drilling. Thus, allow to replenish encountered losses "on the fly" and to save time otherwise required to spend on the drilling fluid preparation. In addition to a technological breakthrough, it is important to emphasize that a high level of Health, Safety, Quality, and Environmental protection (HSQE) was achieved, and no major incidents or accidents were recorded during the entire project. Based on the lessons learned, several engineering, organizational and strategical resolutions were made to further streamline and optimize the well construction process in the field.

Авторское право 2013 г., Общество инженеров нефтегазовой промышленности Этот доклад был подготовлен для презентации на Конференции SPE по разработке месторождений в осложненных условиях и Арктике 15-17 октября 2013 года в Москве, Россия.Данный доклад был выбран для проведения презентации Программным комитетом SPE по результатам экспертизы информации, содержащейся в представленном авторами реферате. Экспертиза содержания доклада Обществом инженеров нефтегазовой промышленности не выполнялась, и внесение исправлений и изменений является обязанностью авторов. Материал в том виде, в котором он представлен, не обязательно отражает точку зрения SPE, его должностных лиц или участников. Электронное копирование, распространение или хранение любой части данного доклада без предварительного письменного согласия SPE запрещается. Разрешение на воспроизведение в печатном виде распространяется только на реферат объемом не более 300 слов; при этом копировать иллюстрации не разрешается. Реферат должен содержать явно выраженную ссылку на авторское право SPE.

Riphean anisotropic cavernous-fissured carbonate reservoirs of oilfield at East Siberia area – one of the most problematic objects of oil and gas production described in this article. Here is discussed geological substantiation and first result of new technology involving in drilling of Riphean carbonate reservoirs with "Controlled pressure technology" by recovery wells with horizontal bottom at the oil-gas condensate field in Evenki Region. Comparison results of conventional drilling and "MPD" (Managed Pressure Drilling) technology. Riphean reservoirs drilling process could be provided in two options. The first one – horizontal conventional drilling. As far as the bit penetrates into the reservoir we are seeing SPP (Stand Pipe Pressure) decrease which means we have total lost circulation. There was only one means for resolving this problem – using LCM (Lost Circulation Material). Due to complicated geology and high parameter of gas factor in Riphean reservoirs (losses while circulation/ gains while static), LCM was insufficient solution. The second is to perform drilling process using MPD (Managed Pressure Drilling) technology. We have the advantage using lower mud weight compared with conventional drilling. MPD technology corresponds with geological conditions of Riphean reservoirs and can be more profitable in future production from these wells. MPD technology with closed loop circulation system showed that we can "manage" BHP (Bottom Hole Pressure) and it really works in temperature conditions of 45 Celsius below zero in Evenki Region (East Siberia). In practice we have seen, that it was possible to achieve more gentle management of BHP than with conventional drilling using LCM. Also with "MPD" system in this oilfield we were able to drill the first ERD (Extended Reach Drilling) well. However, even with such extended horizontal section (1000 meters), a significant reduction of losses was achieved without using LCM. Total results of MPD technology we will see after DST (Drill Stem Test) of drilled wells. New technology showed that it was a right choice to use close loop system and MPD. Also for drilling new wells in this Riphean carbonate reservoirs of this oilfield area we will use this experience. Best way to reduce catastrophic losses in abnormally low pressure reservoir conditions is reduce and control the ECD and details how to achieve it we have considered in this article. The results: Reduced interval construction time. From 31 days to 24 days.Reduced fluid loss during drilling. From 2000 m3 to 1200 m3.Improved the operational safety by closing the loop and real time early kick and loss detection.

In the past few decades, well depths and conditions have grown significantly, and the regulatory environment has become more comprehensive. High temperatures and pressures, and narrow-to-nonexistent drilling windows have hindered the development of assets and substantially increased risks and the cost of hazard mitigation generated by high drilling costs and time spent on well control incidents. From land rigs to semisubmersibles, closing the loop opens the door to a flexible set of drilling capabilities that improve safety of personnel, environment, and equipment while optimizing economics. In each drilling operation the key to success is the use of versatile closed-loop drilling methodologies to meet varied operational and economic objectives. In Arctic conditions, the challenges are to overpass potential risk of environmental spills and optimize AFEs through mitigation of NPTs. Rotating control devices (RCD), which has secured a strong position in the industry, will be a considerable source to hit above targets. RCDs—whether as a top on the BOP stack or as an integral part of a riser system — is a safe and easy way to monitor pressure within the closed loop and divert the drilling fluids safely from the rig floor. Integration of RCD in conjunction with early kick/loss detection and control systems through manipulation of surface backpressure, allows access to more accurate real-time downhole data, resulting in the ability to better manage downhole pressures. Changing choke settings results in a rapid modification of bottomhole pressure throughout the wellbore without the cost and effort of changing mud weight. The closed loop method cuts across operational and economic applications to enable, for instance, the drilling of previously undrillable.

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