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Collaborating Authors
Irkutsk Oblast
Russia and China are nearing agreement on a 2024 construction start for the long-discussed 6700 km Power of Siberia 2 (PoS2) pipeline that would deliver Russian gas from West Siberia, previously designated for European export, to industrial areas north of Beijing via Mongolia by 2030. The proposed pipeline's 50 Bcm/year capacity nearly matches that of the 55 Bcm/year Nord Stream 1 which had carried a third of Russian gas deliveries to the EU before being shut down in September. Once built, PoS2 would double Russia's current gas exports to China as it would join up with the Russian gas network that connects to the Yamal Peninsula (West Siberia), enabling Russia to direct gas to markets east or west at will. After 3 days of talks in Moscow with Chinese President Xi Jinping in March, Russia's President Vladimir Putin announced that "nearly all parameters" have been decided to proceed with PoS2. Authorities anticipate a 2024 construction start.
- Asia > Russia > Far Eastern Federal District (1.00)
- Asia > China > Beijing > Beijing (0.28)
- Europe > Russia > Central Federal District > Moscow Oblast > Moscow (0.26)
- (2 more...)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Midstream (1.00)
- Government > Regional Government > Europe Government > Russia Government (0.70)
- (2 more...)
- Asia > Russia > Siberian Federal District > Irkutsk Oblast > Irkutsk Basin > Kovyktinskoye Field (0.99)
- Asia > Russia > Far Eastern Federal District > Sakhalin Island > Sea of Okhotsk > East Sakhalin - Central Sea of Okhotsk Basin > North Sakhalin Basin > Kirinsky Block > Kirinskoye Field > Kirinskoye Formation (0.99)
- Asia > Russia > Far Eastern Federal District > Sakha Republic (Yakutia) > East Siberian Basin > Nepa-Botuoba Basin > Chayandinskoye Field (0.99)
Maximizing Recovery and Reducing Well Cost Using Herringbone Multilateral Horizontal Well Drilling and Completion Technology
Zhang, Xiaocheng (CNOOC China Limited, TianJin Branch) | Xie, Tao (State Key Laboratory Offshore Oil Exploitation CNOOC China Limited) | Huo, Hongbo (CNOOC China Limited, TianJin Branch) | He, Ruibing (State Key Laboratory Offshore Oil Exploitation CNOOC China Limited) | Lin, Hai (CNOOC China Limited, TianJin Branch) | Hou, Xinxin (State Key Laboratory Offshore Oil Exploitation CNOOC China Limited) | Xu, Dongsheng (CNOOC China Limited, TianJin Branch)
Abstract With the in-depth development of Bohai Oilfield, China National Offshore Oil Corporation (CNOOC), the water cut of some old wells become too high to produce while nearby remaining recoverable reserves are still considerable. In order to maximize recovery and reduce well construction cost, herringbone multilateral horizontal well drilling and completion technology is employed to increase drainage area of single well and make full use of well slot and old wellbore. Considering the current development of oilfield and the geological characteristics of reservoir, the technical difficulties of herringbone multilateral horizontal well drilling and completion technology including high build-up rate, easy blockage of drilling tools in the sidetracking in open hole, easy collapse and instability of sandwich wall and high requirements for drilling fluid performance are analyzed and solved. This technology has been successfully applied in three wells with total 6 branches and the production of three wells is twice higher than that of conventional horizontal wells with no water cut, which fully verified the reliability of the branch well tools and the feasibility of the technology. Herringbone multilateral horizontal well drilling and completion technology provides a new idea for the treatment of low production and low efficiency wells in a sustainable way and will be widely promoted and applied in Bohai oilfield, which can also provide reference for other high water cut oilfields.
- Asia > China (1.00)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Tazovksy District (0.28)
- Asia > Russia > Siberian Federal District > Krasnoyarsk Krai (0.28)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > China Government (0.55)
- Asia > Russia > Siberian Federal District > Krasnoyarsk Krai > Vankorskaya Area > Vankorskoye Field (0.99)
- Asia > Russia > Siberian Federal District > Irkutsk Oblast > Kataganskiy District > East Siberian Basin > Nepa-Botuoba Basin > Verhnechonskoye Field (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Tazovksy District > West Siberian Basin > South Kara/Yamal Basin > Messoyakhskoye Field (0.97)
- (2 more...)
Abstract The presence of halite cement is a little appreciated problem in petrophysical interpretation. Yet halite is common as a late diagenetic cementing phase associated with high salinity formation water and is recognized in many of the world's major petroleum basins. Undetected halite cement leads to a significant overestimation of porosity and permeability during petrophysical interpretation. However, halite cement does not have a unique signature on electric logs and is often not represented in core samples. Current best logging practices are inadequate for the quantification of halite cement. Open hole sigma is a recommended logging solution. Scanning Electron Microscopy with Energy Dispersive Spectroscopy can detect halite. This is a rock imaging technique, performed on either cuttings or core. The images can distinguish between layered depositional halite and pore-filling diagenetic halite cement. Occurrences of non-authigenic halite, precipitated as the rock sample is brought to the surface, have a high surface area and are easily removed by sample cleaning. Conventional core analysis can both identify and quantify halite cement. However standard core cleaning methods operate on the premise that all halite is non-authigenic and thus intentionally remove it. Best practice core handling, processing and testing protocols must be followed and, because halite cement is commonly patchy and discontinuous, the core cleaning and drying study must comprise a large number of plugs. Oil-based mud must be used to cut the core. The effects on porosity and permeability of halite cement can be understood with reference to pore and halite size distributions. Halite cement in sandstones occurs as intergranular pore-occluding cement and is observed most commonly in ~5p.u. layers just a few meters thick. These layers have the same density and neutron log responses as a ~8-12p.u. sandstone filled with gas or light hydrocarbons. Detailed sample-bysample log interpretation in the context of the regional geology is the only way to correctly identify these features. Halite cement is usually found best developed in the cleanest and thickest parts of the reservoir. It most commonly occurs in terrigenous clastic sediments. Proximity to bedded salt is the critical factor. Case studies from the North Sea, the Berkine Basin, the West African PreSalt and East Siberia are discussed.
- North America > United States (1.00)
- Europe (1.00)
- Africa > Middle East > Algeria > Eastern Algeria (0.25)
- Proterozoic (0.68)
- Phanerozoic > Paleozoic (0.68)
- Phanerozoic > Mesozoic > Jurassic (0.46)
- Geology > Mineral > Halide > Halite (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.58)
- North America > United States > Michigan > Michigan Basin (0.99)
- North America > United States > Gulf of Mexico > Norphlet Formation (0.99)
- Asia > Russia > Siberian Federal District > Irkutsk Oblast > Kataganskiy District > East Siberian Basin > Nepa-Botuoba Basin > Verhnechonskoye Field (0.99)
- (15 more...)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Core analysis (1.00)
The Lower Cambrian halogen-carbonate deposits are currently the most promising for the search for oil and gas objects within the Nepa-Botuba anteclise. The article describes methodical techniques for detailed well log correlation of complicated by trap magmatism log using the Yaraktinskoye field as an example. At the first stage of the research in the studied section of the well, all intervals with recorded magma definition were excluded. It was performed correlation of sections of wells treated in this way. The main features of the block structure of the studied objects before the introduction of trap intrusions are rarely revealed by the nature of the change in the thickness of the members. The effectiveness of this technique increases with the repetition of sequential paleoprofiling. When leveling to the reference boundary, it was established that the formation of the Lower Cambrian deposits in the territory of the Yaraktinskoye field is associated with the โkeyboardโ subsidence of blocks along consedimentary faults. At the second stage, the well sections were correlated with restored intrusions. The results confirmed the presence of previously detected ruptures of infectious diseases. Based on well data only as an example, using the method of sequential paleoprofiling it was shown that the formation of the Lower Cambrian halocarbonate sequences occurred due to the subsidence of adjacent blocks along consedimentary faults. These faults subsequently became possible ways for the intrusion of trap magmatism into sedimentary rocks. It is concluded that, despite the multiplicity of samples and sampling algorithms, it is necessary to find a direction in scientific and methodological development, especially in the study of complex reservoirs.
Abstract The aim of this work is to develop an analytical technique for characterizing formation damage. The oil reservoir of the East Siberian Yaraktinskoe field suffers from salt and organic scales precipitation leading to skin damage. Besides, injection water has sulfates, which precipitate as gypsum in the near wellbore area of production wells and at bottomhole. Historically pressure build-ups (PBU) were used to characterize the evolution and extent of the damage. The use of PBUs leads to the shut in of production. Additionally PBUs in the reservoir provide conclusive results in no more than 22% cases. Based on inconsistent results from PBUs and their cost in production losses, it was of interest to find a better and preferable technique for formation damage control using existing data. The result of that initiative is analytical technique that provides dimensionless productivity index (Jd) range monitoring over time, Jd range comparison to the technical potential and identification of the performance gap range. By identifying the performance gap range, stimulation actions are ordered reestablishing oil production, productivity index (PI) and Jd. The technique is based on transmissibility (kh/ยตB or T) model derived from Kamal and Pan study (2010) and reservoir pressure (Pres or P) model. Stochastic part of the technique is provided by T and Pres error functions. The functions are probability distribution functions (PDF) derived from comparison of the modeled T and Pres with well test measured historical values. Using this T and Pres models and historical data of liquid rates and bottomhole pressures (BHP), we can calculate current and historical Jd, Jd drop relative to historical performance or potential and oil rate potential increment with uncertainty margins (10, 50 and 90 percentile or P10-50-90). The margins are calculated from 10000 stochastic iterations of T and Pres within the PDFs of their error. The technique has enabled to find 14 stimulation candidates during 6 month of use. Overall, 15 stimulations were implemented since one well was stimulated twice. Ten of 14 stimulations increased oil production rate by 4161 bbl/day. Five stimulations were economically unsuccessful due to inappropriate stimulation technology implementation. The technique shows acceptable uncertainty level to make efficient and appropriate decisions for the appropriately chosen stimulation technology. Modeled P50 PIs have good match with more than 85% correlation with well test measured PIs after economically successful stimulation. New analytical technique is presented here, which can be utilized as an automatic process without repeating well tests for routine generation of accurate stimulation plan with numerical assessment of success probability and anticipated oil rate increment uncertainty range. Realization of stimulation potential is simplified to the task of appropriate treatment technology selection and implementation for the candidates from the rating.
- North America > United States > Texas (0.46)
- Asia > Russia > Siberian Federal District > Irkutsk Oblast (0.38)
Geomechanical modeling and multi-stage hydraulic fracturing dolomite reservoir of the Verkhnechonskoye oil and gas condensate field
Kuleshov, Vasiliy (LLC Tyumen Petroleum Research Centre) | Pavlov, Valeriy (LLC Tyumen Petroleum Research Centre) | Pavlyukov, Nikolay (LLC Tyumen Petroleum Research Centre) | Musin, Evgeny (LLC Rosneft - Peer Review and Technical Development Center) | Cherkasov, Sergey (LLC Rosneft - Peer Review and Technical Development Center) | Samoilov, Mikhail (LLC Rosneft - Peer Review and Technical Development Center) | Khokhlov, Danil (JSC Verkhnechonskneftegaz) | Kozyrev, Alexander (JSC Verkhnechonskneftegaz)
ABSTRACT: Taking into account Biot constant and anisotropy of elastic properties of reservoir rocks, 3D geomechanical modeling was performed, integrated into the process of planning designs and execution of hydraulic fracturing/MSHF operations. The object under the study is represented by a low-temperature carbonate-dolomite reservoir, that complicate the process of developing hydrocarbon reserves by a system of horizontal wells with MSHF was carried out on them. The geological feature of the formation is the presence of clay barrier of insignificant thickness, which cause high risks of hydraulic fracturing breakthrough in the underlying highly permeable gas-saturated intervals. As a result, the construction of a high-quality geomechanical model and its synchronous adaptation together with hydraulic fracturing models become the necessary condition to achieve the planned goals of field development.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Dolomite (0.61)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.48)
- Geophysics > Seismic Surveying (0.70)
- Geophysics > Borehole Geophysics (0.48)
- Asia > Russia > Siberian Federal District > Irkutsk Oblast > Kataganskiy District > East Siberian Basin > Nepa-Botuoba Basin > Verhnechonskoye Field (0.99)
- Asia > China > Sichuan > Sichuan Basin (0.99)
Integrated Geomechanical Modeling and Hydraulic Fracturing Design: From Particular Cases to the Overall Result
Samoilov, Mikhail (LLC Rosneft โ Peer Review and Technical Development Center) | Pavlov, Valeriy (LLC Tyumen Petroleum Research Centre) | Pavlyukov, Nikolay (LLC Tyumen Petroleum Research Centre) | Timirtdinov, Aleksandr (LLC Tyumen Petroleum Research Centre)
Objective and scope The objective of the work is to present an adequate workflow for conditioning geomechanical data and hydraulic fracturing design, adjustment and simultaneous verification of a MEM and hydraulic fracture models. These approaches are relevant for greenfields and also can be used when changing field development systems: from vertical fracked wells to a system of horizontal wells with multistage fracs. Methods, techniques, and process description The paper provides examples of issues in hydraulic fracturing planning due to poor attention to the reliability and robustness of geomechanical data. Given the critically of data quality, the authors describe a holistic approach used in collecting, analysing and conditioning data for building a MEM (1D; if necessary, 3D) as the basis of a frac design. Mini-frac is considered not only as a tool for setting the hydraulic fracturing design parameters, but also as a source of data for cross-calibration between the MEM and the hydraulic fracture models. Case studies of various HF models will demonstrate the influence of MEM-and-frac uncertainties and the tools for considering them in practical HF modelling. An approach to systematic clustering of input data for HF designs is described. The importance of measuring the fracture heights is stressed as a source of data for cross-calibration of HF and GM models. Results and conclusions The correct sequence of work, data consolidation and successive data refinement helps to maintain the database of elastic and strength properties of various target reservoirs, which proves the demand for core analysis and well logging, as well as geomechanical modelling. The improved quality of HF designs leads to better reliability of forecasts and proposed field development and individual wellwork strategies. The close integration of GM studies and modelling with HF design building enhances the operation culture, accelerates and streamlines the HF model build and validation processes, which can be a pace-setting experience for other oil and gas industries that are GM data users. Novelty and achievements The TNNC and RN-CEPiTR teams work in close cooperation and provide GM and HF integration to assess the fracture height in the target reservoirs at the Company's assets in order to improve the quality of HF modelling. The uncertainty influence on the HF design is reducing, so as the risks of screen-out and the risks of breakthrough into undesirable zones. The approach streamlines the engineering support for the hydraulic fracturing activity and understanding of the fracture parameters as the operations move from single-stage hydraulic fracturing to the optimized field development using horizontal wells with multi-stage hydraulic fracturing.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.69)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Passive Seismic Surveying > Microseismic Surveying (0.47)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > Central Basin > Kharampurskoye Field (0.99)
- Asia > Russia > Siberian Federal District > Irkutsk Oblast > Kataganskiy District > East Siberian Basin > Nepa-Botuoba Basin > Verhnechonskoye Field (0.99)
Successful Implementation of the PMCD Technology for Drilling and Completing the Well in Incompatible Conditions at Severo โ Danilovskoe Oil & Gas Field
Krivolapov, Dmitry (Schlumberger) | Masalida, Ivan (Schlumberger) | Polyarush, Artem (Schlumberger) | Visloguzov, Vyacheslav (JSC VCNG) | Averkin, Alexey (JSC VCNG) | Rudykh, Artem (JSC VCNG) | Ivanov, Pavel (JSC VCNG)
Abstract This paper discusses the successful implementation of PMCD (Pressurized Mud Cap Drilling) technology at Severo โ 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 pressuresโ 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/cm 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.
- Europe (0.93)
- Asia > Middle East (0.68)
- Asia > Russia > Siberian Federal District > Irkutsk Oblast > Irkutsk (0.24)
- North America > United States > Texas > Dawson County (0.24)
- 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 > Indonesia > Sumatra > Soka Field (0.99)
- (2 more...)
Application of the Advanced Methods to Investigate Incidents and Drilling Engineering Principles to Prevent Critical Wear-Out of Downhole Equipment When Drilling Wells in Chayandinskoye Field
Abaltusov, Nikolay Valerevich (Weatherford) | Ryabov, Anton Sergeevich (Weatherford) | Perunov, Artem Evgenevich (Weatherford) | Rublev, Sergey Sergeevich (Gazpromneft-STC) | Mitrokhin, Sergey Aleksandrovich (Gazpomneft-Zapolyarie) | Mukhachev, Igor Yurevich (Gazpomneft-Zapolyarie) | Fomchenko, Roman Gennadevich (Gazpomneft-Zapolyarie)
Abstract The pressing challenge is the abnormally rapid wear of well logging equipment and drilling tools when drilling wells in pay zone of Chayandinskoye field. Wear-out of BHA stabilizers within one run makes directional drilling inefficient and results in additional trips to replace equipment. Wear-out of drill pipes results in emergencies risk increase. To prevent such incidents the necessity arises to conduct an unscheduled inspection, reject and replace drilling tools. All these conditions entail increase in drilling time and decline in profitability. Problem analysis and expert review was made by drilling optimization specialists from DD Contractor jointly with the experts from R&D Center and Operator Company. This paper discusses how cooperation of the engineers from three companies as well as a particular approach to incident investigation and drilling engineering made it possible to identify the most critical factors, which contribute to a standard BHA wear, to work out measures to prevent similar situations in future and select an alternative BHA. The gained experience has been successfully disseminated to the other wells in Chayandinskoye field and other fields in Eastern Siberia; and the incident investigation methods and drilling engineering procedures are effectively applied under the other projects.
- Geology > Rock Type > Igneous Rock (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.47)
- Geology > Mineral > Sulfide (0.46)
- Asia > Russia > Siberian Federal District > Irkutsk Oblast > Kataganskiy District > East Siberian Basin > Nepa-Botuoba Basin > Verhnechonskoye Field (0.99)
- Asia > Russia > Far Eastern Federal District > Sakha Republic (Yakutia) > East Siberian Basin > Nepa-Botuoba Basin > Chayandinskoye Field (0.99)
Problem of Gas Breakthrough Solved through Installation of Recompletion Assembly with Autonomous Gas Inflow Control Devices AGICD in Oil Producing Wells
Ivanova, Ekaterina Yurievna (NPK Filtr LLC) | Khokhlov, Danil Igorevich (JSC VCNG) | Shangin, Andrey Viktorovich (JSC VCNG) | Nesterov, Pavel Vladimirovich (JSC VCNG) | Britov, Evgeniy Vitalevich (JSC VCNG) | Arzamastsev, Georgiy Georgiyevich (NK Rosneft PJSC)
Abstract During the field tests in oil producing wells at the Verkhnechonskoye field there were autonomous gas inflow control devices (hereinafter referred to as AGICD) applied for the first time as part of a recompletion assembly. The recompletion technology is based on a well completion design solution with AGICD which consists in dividing the liner into intervals, equalizing the total inflow and restriction of the inflow of adverse fluids in producing wells with increasing flowrates of adverse fluids as well as wells shut in due to water/gas breakthroughs. The recompletion assembly is run into the previously lowered liner equipped with sand screens and divided into several zones by swellable packers. The new assembly essentially features the classical completion assembly but comprising original 73-mm-tubing-based equipment such as a shoe, cup packers, a packer hanger, and centralizers. The equipment design allows for its complete retrieval if necessary. Since oil contains a lot of solids and deposits of asphalts, resins, and paraffins, the recompletion assembly has a flush valve enabling acid cleanout of the pay zone of the formation during the operation. In order to prepare for the recompletion assembly to be run in, intense analytical work was done to study the candidate wells and geological conditions and peculiarities of the Verkhnechonskoye field, to analyze the open hole logging data and the oilfield geophysics vs. its hydro-dynamic model data. During the field trials, recompletion assemblies were run in two wells of the Verkhnechonskoye field and monitored to assess their operation with AGICD within a set period of time. Then the equipment was pulled out and the wells were monitored again without AGICD. The findings provided the basis for the assessment of the equipment operation. The analysis of the trials results showed that the equipment is prepared, run in the hole and retrieved in normal mode. The qualitative AGICD performance indicators are based on the stable well operation within the total nonfailure operating time after the recompletion assembly is run in the hole. The quantitative AGICD performance indicators are defined by the achieved gas ratio decrease and oil flowrate rise. The trials also confirmed the convergence of the AGICD expected and field-proven performance indicators which makes it possible to plan precisely well operation modes when using recompletion equipment. The trials findings prove that the recompletion technology is reasonable for wells with high rates of non-targeted fluids as well as idling wells (due to water/gas breakthrough) to make them active again.