bluuebunny/crossref_metadata_2025_split huggingface dataset:
Hollow Glass Spheres HGS in Drilling Fluid: Case Study of Preventing and Mitigating Total Losses
Authors: Sherishorin Vitaly , Rylance Martin , Tuzov Yevgeniy , Krokhaleva Olga , Tikhonov Evgeny , Chirkov Oleg , Ivanov Ruslan 
Published: October 2021

Abstract
The paper describes the first deployment of HGS in Eastern Siberia as a mud additive. The technology was utilized for reducing drilling fluid density for prevention and mitigation of losses; while drilling through a producing reservoir section with low pore pressure, unconsolidated and fractured sands. The engineering considerations, fundamentals of the approach and major risks involved were reviewed with application to the Sredneboutobinskoye Oilfield as a pilot field application for broader future plans.
Key planning, delivery and execution principles of the initial application will be reported in the paper. Initially deployed on three wells, including multi-laterals (Rylance et al., 2021), the paper will walk through the engineering considerations during the planning and execution phases. Key sections include the data gathered and the many lessons learned during the incremental and stepwise deployment. The paper will also report on post drilling productivity and comparisons with the offset wells drilled with conventional mud systems, which suffered severe losses.
The results of this pilot have exceeded expectations. There have been many insights and the Team are now looking to set a timetable to scale-up across the Taas-Yuryakh Neftegazodobycha (TYNGD). After many hours of laboratories study and preparation works, the general plan was to reduce the static density and ECD to mitigate fluid losses. However, the applied results showed additional effects from HGS. Data will be provided that demonstrated loss-free drilling was achieved where this had not been the case before, with a material reduction in NPT, lost circulation material (LCM) needs and costs. Much has been learned, recovered HGS material has been demonstrated to be an effective LCM pill and centralization of mud processing may offer additional cost savings and improvements. Further efficiencies are also expected to be achieved and future potential is considerable.
HGS for cementing is well documented, yet application for drilling fluids has been less well reported and almost exclusively related to single wells. The TYNGD application is innovative as this is a major development with 10 active drilling rigs. The application is on multi-laterals and offset wells are available for direct comparison. The results of the approach demonstrate a new way of performing well construction in an effective manner for major field developments where losses are prevalent.
Engineering Fluids and Hydraulics to Drill the First Sub-Horizontal Well with Narrow ECD Window in Eastern Urengoy License Area
Authors: Sergeev Pavel Nikolayevich , Mordyukov Alexander Fyodorovich , Kozyrev Alexander Sergeyevich , Bembak Evgeny Vasilyevich , Matsera Aleksander Mikhailovich , Kabanov Alexander Viktorovich , Tikhonov Evgeny Vladimirovich , Kharitonov Andrey Borisovich 
Published: October 2021

Abstract
The Operator's challenge was the construction of a sub-horizontal well with 1500 m liner section in area with limited offset experience. The main development difficulty of the East Urengoy license area is the abnormally high pore pressure Achimov deposit. The widely used practice of drilling for these reservoirs with S-shaped profile wells has been utilized for a long while. However, the construction of sub-horizontal wells is still a challenge, and often accompanied by high incident rates.
Before drilling the well, all necessary fluid engineering modelling was performed. According to the hydraulic calculations, drilling of the horizontal well with traditional fluid properties was not possible due to exceeding the maximum ECD range. Multiple laboratory tests were performed to optimize the drilling fluid parameters and rheological properties with respect to ECD reduction and reducing potential for weight fluctuations due to barite sag. Based on the data obtained, recommendations were issued to predict ECD levels while drilling and tripping. At the same time, step-by-step action plans were developed for trouble-free drilling.
While utilizing this optimized fluid, with close interaction and cooperation between the project Operator (ROSPAN International), the Customer's research and development center, technical support service and the drilling contractor, the first sub-horizontal well on this licensed site has been successfully drilled.
The following main actions were developed and executed during the well construction process:
Maintained the hydraulic pressure (marginally) above the pore pressure through careful fluid management. The rheological properties of the drilling fluid were maintained to the developed (lab verified) specifications. Careful hydraulic pressure management during tripping. Extensive planning of the tripping operations included increasing the mud weight before tripping to create the necessary margin and optimization of the tripping rate. Ensuring effective drilling parameters and preparing the wellbore for the casing run according to hydraulic calculations. Recommended optimized drilling fluid parameters aimed at preventing barite sag under abnormally high pore pressure and high bottom hole temperatures (up to 110 deg C). Use of specialized pills to assist prevent the loss of circulation and wellbore instability.
This article is devoted to the development of drilling fluid solutions and practical techniques for effectively drilling wells in the area with challenging formations. This case study, as well as the lessons learned will be used for ongoing drilling projects in the area.
Remote Reservoir Exploration in Odoptu-More Field by Delivering ERD Wells Using Multilateral Drilling Technology
Authors: Shakhova Anna , Lisyutina Natalia , Lebedeva Irina , Valshin Oleg , Savinov Roman , Famiev Robert , Dementyev Alexander , Marushkin Dmitry , Bochkarev Vladimir , Surmin Vladimir , Bolychev Evgeny 
Published: October 2021

Abstract
This paper provides the results that were achieved and shares the drilling unique practices that were implemented to deliver the first complex bilateral extended reach drilling (ERD) well in Odoptu-more field (North Dome).
Well design driven by geological objectives considered drilling 215.9mm main and pilot holes (PH). Well complexity was governed by the type of a profile having ERD ratio of 5.22 (main hole) / 4.60 (PH) and trajectory's 3D nature (turn in azimuth of 90 degrees) compared to previous wells in the project drilled mainly with 2D profiles. Apart from the problems connected with drilling and casing upper sections key challenges comprised kicking off in 215.9mm open hole at 5955m MD and 1512m TVD with rotary steerable system, setting cement plugs at shallow true vertical depth (TVD) at 89 degrees of inclination to abandon laterally drilled PH, delivering 168.3mm production liner to bottom with a risk of entering a lateral while running in hole.
An effective collaboration between integrated engineering team and customer departments went far beyond ERD standard set of operations already existing in the project thus allowing to break its own records and to set new achievements due to integrated technological approach. The longest 444.5mm section (2975 m) was drilled in one run achieving the record daily drilling rate and rate of penetration (ROP). Cementing of 244.5mm floated liner resulted in the highest good cement bond integrity percentage ever achieved among other wells in project due to new ways of casing standoff and fluid rheology hierarchy modeling. For the first time in the project 215.9mm main horizontal hole in extreme reach ERD well has been drilled by kicking off in open hole from the pilot horizontal one with push-the-bit rotary steerable system without a kickoff plug with pilot hole being abandoned by setting cement plugs. Project-specific risk assessment conducted by team allowed successful deployment of 168.3mm liner into the main hole. Moreover, due to thorough engineering planning electrical submersible pump (ESP) was run without extending 244.5mm liner to surface by tie-back thus saving additional 7 days.
Drilling first bilateral ERD well unlocked opportunities for the operator to reach, explore and develop different extended geological targets thus eliminating well construction process of additional wells on drilling upper sections.
TAML-3 Multilateral Wells Construction with Multi-Stage Fracturing in Producing Wells
Authors: Tuzhilkin Stanislav Vladimirovich , Brednev Filipp Igorevich , Yastreb Andrey Vladimirovich , Uchuev Ruslan Pavlovich , Parshakov Andrey Evgenievich , Zubaidullin Rustam Ravilievich , Islamov Azamat Ildarovich , Burkov Andrey Alexeevich 
Published: October 2021

Abstract
The article presents geological substantiations, the process and the results of the construction of a multilateral well with multistage fracturing from the existing producing well in the Yuzhno-Priobskoye field. The scope of construction of a multilateral TAML-3 well as per the international classification with a saved mainbore was to prove the effectiveness of the multilateral technology and its economic feasibility in the conditions of an extensive stock of producing wells.
Every year we are seeing an increasing number of new wells being drilled in reservoirs with worsening characteristics which is caused by low permeability. Sharp production declines (up to 70% in the first year) and an increasing amount of periodic wells highlight the need to advance well stimulation methods. Well workovers by drilling a horizontal lateral while keeping the mainbore in operation allows to increase the production rate by 30% compared to a conventional sidetracking. While keeping the production rate of the mainbore, this technology provides for an additional production from a lateral bore and allows to operate the well at the planned bottomhole pressure.
Development and Implementation of the Method of Cementing Production Casing 178 mm with Pressure on the Cement Slurry on the East Part of the Orenburg Oil and Gas Condensate Field
Authors: Miklyaev Maxim Viktorovich , Denisov Ivan Vyacheslavovich , Gavrilin Ivan Mikhailovich 
Published: October 2021

Abstract
Well construction in the Volga-Ural Region faces different sorts of complications, the most common ones being the loss of drilling fluids and rockslides. Such complications may cause considerable financial losses due to non-productive time (NPT) and longer well construction periods. Moreover, there are complications, which might occur both during well construction and during its exploitation. The commonest complications are sustained casing pressure (SCP) and annular flow.
The complications, which occur when operating a well, also have a negative effect on the economic efficiency of well operation and call for additional actions, for example, repair and insulation works, which require well shutdown and killing, though a desired outcome still cannot be guaranteed; moreover, it is possible that several different operations may have to be carried out.
In addition, the occurrence of SCP during well life is one of the most crucial problems that may cause well abandonment due to high risks posed by its operation. It is known that the main reasons for SCP are as follows:
Channels in cement stone Casing leaks Leaks in wellhead connections
To resolve the problem of cement stone channeling, several measures were taken, such as revising cement slurry designs, cutting time for setting strings on slips, applying two-stage cementing, etc. These measures were not successful, besides, they caused additional expenses for extra equipment (for example, a cementer). In order to reduce the risk of cement stone channeling, a cementing method is required that will allow to apply excess pressure on cement slurry during the period of transition and early strength development. To achieve this goal, a well-known method of controlled pressure cementing may be applied. Its main drawback, however, is that it requires much extra equipment, thus increasing operation expenses. In addition, the abovementioned method allows affecting the cement stone only during the operation process and / or during the waiting on cement (WOC) time.
Upon receiving the results of the implemented measures and considering the existing technologies and evaluating the economic efficiency, the need was flagged for developing a combined cementing method. The goal of this method is to modify the production string cementing method with a view to applying excess pressure on cement stone during strength development and throughout the well lifecycle. The introduction of this lining method does not lead to an increase in well construction costs and considerably reduces the risks of losing a well from the production well stock.
Successful Implementation of the PMCD Technology for Drilling and Completing the Well in Incompatible Conditions at Severo – Danilovskoe Oil & Gas Field
Authors: Krivolapov Dmitry , Masalida Ivan , Polyarush Artem , Visloguzov Vyacheslav , Averkin Alexey , Rudykh Artem , Ivanov Pavel 
Published: October 2021

Abstract
This paper discusses the successful implementation of PMCD (Pressurized Mud Cap Drilling) technology at Severo – Danilovskoe oil and gas field (SDO) located in the Irkutsk region. The abnormally high-pressure reservoir B1 and the abnormally low-pressure reservoir B5 are the target layers in this field. Wells drilling at SDO is accompanied with simultaneous mud losses and inflows conditions, especially if the strata B1 is being penetrated. Pumping lost circulation materials (LCM) and cement plugs do not solve lost circulation complications which subsequently lead to oil and gas inflows. As a result, most of such wells are getting abandoned.
It was assumed that complications in this formation occurs due to the narrow safe pressures’ operating window (ECD window), therefore, the managed pressure drilling technology (MPD) was initially used as a solution to this problem. However, after the penetration of the abnormally high formation pressure B1 horizon with a pore pressure gradient of 1.86 g/cm3 it was found that there is no operating window. In this regard, there were simultaneous mud losses and oil and gas inflows during the circulation. The well was gradually replaced by oil and gas, regardless of the applied surface back pressure value in the MPD system. The mixing of the mud and reservoir fluid was accompanied by catastrophic contamination. As a result, the drilling mud became non - flowing plugging both the mud cleaning system and the gas separator. On the other hand, the plugging of the B1 formation with LCM did not bring any positive results. Bullheading the well followed by drilling with applied surface back pressure and partial mud losses gave only a temporary result and required a large amount of resources.
An implementation of PMCD technology instead of MPD has been proposed as an alternative solution to the problem. This technology made it possible to drill the well to the designed depth (2904 - 3010 m interval). For tripping operations, as well as the subsequent running of the production liner it was necessary to develop an integrated plan for well killing and completion in extreme instability conditions. As a result of various killing techniques application, it became possible to achieve the stability of the well for 1 hour. Oil and gas inflows inevitably occurred when the 1 hour lasted. Based on these conditions, the tripping and well completion process was adapted, which in the end made it possible to successfully complete the well, run the liner and activate the hanger in the abnormally high-pressure reservoir.
Innovative Approach to Analysis Drilling Tool Works
Authors: Gubaidullin Ramil Ilshatovich 
Published: October 2021

Abstract
Information technologies have long been an integral part of our lives, and the oil and gas industry has also undergone natural IT evolution. Modern technologies have allowed to automate the basic processes and structure the existing order of work, but there are still unresolved problems, one of which is monitoring the full life cycle of drill pipes and predicting the accumulation of fatigue damage. In most cases, the failure of the drill pipes is associated with fatigue destruction, which begins with microcracks as a result of exposure to variable stresses during the construction of the well (drilling).
Currently, there are no effective methods to control accumulated fatigue damage or residual durability of the pipe at a given level of stress. In this regard, a system is required for a more reliable assessment of the condition of the drill pipes, which will take into account the whole list of factors influencing the rate of accumulation of fatigue damage in the body of the pipe and will allow to calculate (predict) the accumulated fatigue of the drilling pipes, using data from drilling regimes and well parameters.
Understanding the mechanism of accumulation of fatigue wear, which leads to the failure of drilling pipes, makes it possible to manage this process, significantly reduce the cost of maintenance of the drilling pipe fund and reduce incidents with drilling pipes.
Analytical Resources of Digital Procedures in Monitoring and Controlling the Processes in Drilling the Wells
Authors: Kozhin Vladimir Nickolayevich , Patorov Aleksey Anatolevich , Lunin Evgeniy Alekseevich , Davletov Kamil Rafikovich 
Published: October 2021

Abstract
Drilling is traditionally considered as one of the most challenging and expensive areas in oil and gas industry, and its efficiency, against the background with the of unstable forecast in current situation with growing oil prices, both defines the efficiency of capital investments at well construction stage and the cost of production as a whole. Changing drilling conditions, such as well depths, their complicated architectures due to reservoir depletion and their complex localization conditions, pose the task of attracting advanced technologies aimed at modifying the labor process, reduction in costs and increase in production efficiency ("GazpromNeft", 2015). However, not all such procedures are mass-produced due to high price that you need to pay for them, as well as possible limitations of obtaining these technologies. There is a need to implement the tasks in short term with the available resources without involving any expensive equipment and additional personnel (Litvinenko et al., 2017). This opportunity is opened by effective data management in the progress of well construction as well as in information and analytical supporting tools that allow you to receive, process and control this data in a short time and to take the appropriate management decisions based on it (Ivanov, 2017).
Of course, one of the foundations in the controlling over the industrial processes is the reference book of time standards to perform basic operations in drilling and casing the wells (Unified Time Regulations in Process, 1987), which is mainly aimed at preventing unjustified costs during the process of well construction (excess time), planning the duration of operations, conducting procedures to select the applicants for work.
Development and Implementation of Green Inhibitors of Gas Hydrate Formation in the Fields of Western Siberia
Authors: Voloshin Aleksander , Nifantiev Nikolay , Egorov Mikhail , Alimbekov Robert , Dokichev Vladimir 
Published: October 2021

Abstract
The effect of biodegradable polysaccharides – sodium (NaCMC) and ethanolammonium salts of carboxymethylcellulose, dextran and arabinogalactan on the process of gas hydrate formation was studied in order to search for new "green" inhibitors of low-concentration gas hydrate formation. The ability of polysaccharides to inhibit gas hydrate formation was studied in a quasi-equilibrium thermodynamic experiment. A mixture of hydrocarbon gases with a composition typical of the composition of petroleum gas and containing 78% methane was used as a gas-hydrate-forming model medium. It was found that in concentrations of 0.005, 0.0065 and 0.008%, dextran, NaCMC and arabinogalactan as thermodynamic inhibitors exceed methanol by 170-270 times in inhibitory properties. Dextran is superior to NaCMC and arabinogalactan in terms of inhibition efficiency, reduction of gas hydrate formation rate and induction time. Since with an increase in the concentration of polysaccharides, the pressure drop of gas hydrate formation increases and the rate of formation of gas hydrates decreases according to the mechanism of action, the studied polysaccharides can be attributed to both thermodynamic and kinetic inhibitors. It is established that the molecular weight of water-soluble polysaccharides has a significant effect on their inhibitory properties. A polysaccharide with a molecular weight of 250,000 demonstrated the highest inhibitory activity among the studied samples of NaCMC, which is 400 times more effective than methanol. NaCMC with a mass of 700 thousand did not have any effect on the formation of hydrates. Among the ethanolammonium salts, the monoethanolammonium salt CMC showed the greatest effectiveness in inhibiting the formation of tetrahydrofuran hydrates. An increase in its concentration from 0.02 to 0.1% leads to an increase in the induction time required for the nucleation and subsequent growth of crystals by 10 times. When switching from mono - to di - and triethanolammonium salts of carboxymethylcellulose, the inhibition efficiency decreases. It is shown that sodium and ethanolammonium salts of carboxymethylcellulose, arabinogalactan and dextran are promising for creating new "green" highly effective inhibitors of gas hydrate formation on their basis. The results of laboratory and field tests of the preparative form of the "green" gas hydrate formation inhibitor at the fields of Western Siberia are presented. It was found that at dosages of 500 g/m3 or less, there is no formation of hydrate plugs in the annulus of wells.
Development of an Innovational Multiphase X-Ray Flowmeter
Authors: Zubakin Andrey Anatolievich , Davydov Aleksandr Igorevich , Gogolev Aleksey Sergeyevich , Chistyakov Sergey Gennadievich , Filatov Nikolay Alexandrovich , Boyev Artem Sergeyevich , Rukavishnikov Valeriy Sergeyevich 
Published: October 2021

Abstract
Non-separation measurement of a multiphase mixture coming from an oil well is traditionally considered a complex measurement, for which rather expensive solutions are used, including non-trivial maintenance.
This work aims to describe a new technology in the area of measuring multiphase oil and gas-water mixture, which is being finalized by specialists of the Tomsk Polytechnic University for conducting pilot tests at the facilities of Zarubezhneft JSC, and to indicate a more informative level of measurement of oil and gas industry production, which allows measuring the amount of oil, gas and water with high precision without the use of radioactive sources and constriction devices.
The purpose of measuring a multiphase mixture is to determine the amount of oil, gas and water. In order to do this, it is required to determine the total flow rate of the mixture and the distribution of the flow by substances and phases: oil gas, oil and formation water. The total flow rate in the developed multiphase X-ray flowmeter is based on cross-correlation analysis of radiograms from two linear detectors. Measurement of the component composition for the purpose of the distribution of the flow by substances and phases is carried out by the method of two-wave absorptiometry.