he best industrial practices that cover the life cycle of a new technology development as well as supporting procedure are reviewed to investigate the drivers for higher efficiency and better management of variable expectations and technology maturity for further roll-out. The update of the Upstream technological portfolio will increase its adaptability and value and expand project managers’ financial and organizational authority while project initiation and implementation. In this article we investigate various methodologies and tools for technology management in order to find an optimal one. Finally, it is concluded that the combination of classic stage-gate approach and agile best practices demonstrate a good potential for technology management in Gazprom Neft. Such hybrid methodology has a higher level of efficiency and helps meet current company needs in terms of speed and quality of technology implementation in given macroeconomic conditions.

References

1. Spath J., Transforming the upstream service industry to increase operator margins, Journal of Petroleum Technology, 2016, V. 68, no. 05, pp. 54–57.

2. Daft R.L., Kendrick M., Vershinina N., Management, Mason, Ohio: South Western, Cengage Learning, 2010, 856 p.

3. Cooper R.G., What’s next? After stage-gate. Progressive companies are developing a new generation of idea-to-launch processes, Research-Technology Management, 2014, pp. 20–31.

4. Yakovlev V.V., Khasanov M.M., Prokofiev D.O. et al., Technology development in upstream division of Gazprom Neft, Journal of Petroleum Technology, 2017, V. 69–4.

Robust management is the determination of goals and decisions with a given probability while maximizing the expected value facing uncertainties. An obvious specificity and the advantage of robust management is that it allows to account simultaneously expected costs and chance of success. Which means that the developed strategy will allow to achieve the goal regardless the outcome of uncertainties. This makes possible to analyze risks when making decisions and to develop a goal achieving strategy. Currently, the principles of robust management are implemented in many areas, but it is especially valuable in greenfield development projects due to the high degree of uncertainty. The geological uncertainties are the main in oilfield development. Due to the large number of loosely coupled reservoirs and the long phases of the oilfield exploration, the robust optimization allows to take into account all incoming information and making the best decision for further development.

The paper examines the use of robust management to determine the optimal strategy for the development of assets, ensuring the achievement of a certain level of production with a given probability. Gazprom Neft PJSC tested the robust management approaches on ten exploration projects. A strategy that takes into account the information received during the development and research of these assets was found as a result. This strategy allows to “react” and accelerate the development of the remaining assets in case of unfavorable uncertainty outcomes, and “react” and slow down or postpone the development of the remaining assets in case of favorable outcomes in order to maintain plateau oil rate. Finally, the strategy allows to achieve the optimal expected monetary value with probability limit.

References

1. Kalra N., Groves D.G., Bonzanigo L. et al., Robust decision-making in the water sector: a strategy for implementing Lima's long-term water resources master plan, WPS7439, 2015.

2. Alpak F.O., Long J., Ramirez B.A., Robust optimization of well placement in geologically complex reservoirs, SPE 175106-MS, 2015.

3. Nguyen Ngoc T.B., Dang C.T.Q., Long X.N. et al., Robust optimization of unconventional reservoirs under uncertainties, SPE 180108-MS, 2016.

The Domanic formation is a complex object for the prediction and modeling of promising zones with the presence of mobile hydrocarbons. This is due to the low level of knowledge of the object, the features of the structure and there are no unambiguous criteria that determine the prospects of deposits of this type.

The Domanic formation only recently began to be considered from the position of oil content in contrast to the Bazhenov formation. There is little data on inflow from the Domanic formation and the results of core studies. Deposits are of great interest in terms of increasing the resource base of Gazprom Neft.

The object of research is characterized by a thin-layered structure with lateral and vertical unevenness, as well as the presence of a sporadically developed reservoir inside the complex. Localization of prospective areas for search of hydrocarbon deposits is a non-trivial task. The paper used an integrated approach to research, taking into account the features of the geological structure and determining the key parameters of the prospects of the object. «Sweets spots» were identified on the generalization of data on core analysis, interpretation of logging, reinterpretation of seismic data and data of potential fields.

The publication will show the key defined geological, geophysical and geochemical parameters, which are interpreted in the allocation of promising areas for high-bituminous deposits of Domanic type, as well as a complex of geological exploration used to study unconventional deposits in Gazprom Neft.

References

1. Alekseev A.D., Antonenko A.A., Zhukov V.V., Strizhnev K.V., The differentiated approach of the reserves estimation for source rock formations (In Russ.), SPE 182074-RU, 2016.

2. Popov Yu.A., Popov E.Yu., Chekhonin E.M. et al., Investigation of Bazhenov formation using thermal core logging technique (In Russ.), Neftyanoe Khozyaystvo = Oil Industry, 2017, no. 3, pp. 22–27.

The paper introduces new results regarding the spectral approach to geological modelling which extends it by providing means to involve data on horizontal wells in the process of spectral simulation. An analytical algorithm for conditioning random fields of 3D geological property simulated by the spectral method on horizontal wells data is described. The algorithm is based on generalization of kriging and two-step conditioning of stationary stochastic fields, based on that generalization. Numerical algorithms are provided for analytical derivations and implemented in program code in order to assess practical applicability of the method.

In order to demonstrate efficiency of the new method two models of sand distribution for a reservoir containing significant number of horizontal wells were simulated. The first one was simulated by means of conventional spectral approach, based only on vertical wells, and the second one was simulated by new method, based on all wells, including horizontal ones. Comparison of the two models showed that the second model, while preserving statistical characteristics of the well data as good as the first model, precisely reproduced data along horizontal well, thus increasing prognostic ability of the geological model. The results presented in the paper eliminate one of the main limitations of the spectral approach to geological modelling and significantly widen its practical application scope.

References

1. Baykov V.A., Bakirov N.K., Yakovlev A.A., New methods in the theory of geostatistical modelling (In Russ.), Vestnik Ufimskogo gosudarstvennogo aviatsionnogo tekhnicheskogo universiteta, 2010, V. 14, no. 2 (37), pp. 209-215.

2. Baykov V.А., Bakirov N.K., Yakovlev A.A., Matematicheskaya geologiya (Mathematical geology), Part 1. Vvedenie v geostatistiku (Introduction to geostatistics), Moscow – Izhevsk: Publ. of Institute of Computer Science, 2012, 228 p.

3. Khasanov M.M., Belozerov B.V., Bochkov A.S. et al., Application of the spectral theory to the analysis and modelling of the rock properties of the reservoir (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2014, no. 12, pp. 60–64.

4. Ismagilov N.S., Lifshits M.A., Conditioning spectral simulation method by horizontal well data, Proceedings of ECMOR XVI-16th European Conference on the Mathematics of Oil Recovery, 2018. – http://earthdoc.eage.org/publication/result?edid=561

At the beginning of 2017, Gazprom Neft received a license to study and develop the Ayashsky license area and in the summer of the same year a large Neptune oil field was discovered in the new region.

The main geodynamic stages of its evolution were considered during the study of the territory. This made it possible to assess the impact of tectonic processes on the geological structure of the productive horizons and the features of the sedimentary cover formation. The actual geological and geophysical information of the first appraisal well, seismic and regional data were also compared.

According to the results of a detailed description of the core material of the well no.1 Ayashskaya geological features were identified. These features indicate the subsidence of the basin in the process of sedimentation, as a consequence of the formation of aggradation complexes, as well as volcanic activity, which accompanied all stages of the sedimentary cover formation in the region. In this article, the authors have attempted to describe the most likely concept of the formation of productive horizons of the Neptune oilfield.

Today, there are many geological uncertainties and technological challenges associated with the work in the region. All these issues require further study and in-depth study for the successful launch of the field into development.

References

1. Shein V.S., Ignatova V.A., Geodinamika i perspektivy neftegazonosnosti osadochnykh basseynov Dal'nego Vostoka (Geodynamics and oil and gas potential of sedimentary basins of the Far East), Moscow, Publ. of VNIGNI, 2007, 296 p.

2. Gladenkov Yu.B., Kaynozoy Sakhalina i ego neftegazonosnost' (Cenozoic of Sakhalin and its oil and gas potential), Moscow: Geos Publ., 2002, 226 p.

The development of oil rims involves significant difficulties and requires detailed feasibility studies to justify drilling of high-tech wells. At the designing stage of Novoportovskoye field development, a decision was made to drill 1,000–1,500 m horizontal wells. In 2015–2016, the project team developed a technology plan that included an assessment of technological availability to drill complex design wells and selection of geological targets for testing and subsequent economic evaluation. A feasibility study of well completion combination based on calculations using a reservoir simulation model allows one to take into account various geological and physical conditions for each project well, wells interference, and also to evaluate various recovery methods, taking into account changes in the well completion. The paper describes the results of testing wells with various completions, analysis of their performance in various geological and physical conditions, as well as approaches to development design (rolling out) based on well completions mapping. The analysis will focus on J2-6 and NP8 reservoirs which have varying reservoir properties and free gas/oil reserves ratios.

Selection of the J3 reservoir in the geological cross section, in which considerable part of oil and gas reserves is concentrated, and position of J3 relative to fluid contacts in combination with the degree of clay formation of the whole section allowed to form a matrix of characteristic oil rim zones. Based on this matrix, a well completion technology zoning map was constructed. The design solutions recommended on the basis of the developed algorithms for calculating the efficiency of completion for various geological and physical conditions were confirmed by the results of actual well operation. Considering the results obtained, the potential for replication of the combined development systems to other reservoir fields in particular NP8 reservoir was obvious.

The combination of different types of well completion based on geological conditions, technological readiness and economic evaluation allows to increase both the oil recovery factor and the economic efficiency of reservoir development.

References

1. Badgutdinov R.R., Apasov R.T., Fedorov M.V. et al., Technological challenges of oil rim development in terms of Novoportovskoe field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 12, pp. 56–59.

2. Sugaipov D.A., Bazhenov D.Yu., Devyat'yarov S.S. et al., Integrated approach to oil rim development in terms of Novoportovskoye field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 12, pp. 60–63.

3. Sugaipov D.A., Rustamov I.F., Ushmaev O.S. et al., Results of multilateral drilling on Novoportovskoye field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 12, pp. 35–36.

4. Pil'nik S., Dubrovin A., Zimoglyad M. et al., Proven experience in construction of multilateral wells using TAML 1 technology in Novoportovskoye field (In Russ.), SPE 191521-18RPTC-RU, 2018.

Cost-effective production from Achimov reservoirs is impossible without technological development. For such a complex reservoirs oil companies have to take in account a wide range of technologies and technological challenges have to be solved in a complex way with strong cross-functional cooperation. This paper provides a review of technological challenges that Gazpromneft faces with. The purpose of this study was to identify unique Achimov technological challenges and find out prospective technologies to make a complex concept of technological development. The article describes in a brief geological background for technological challenges and their description. Challenges were grouped into three technological streamlines that are reserves localization and properties determination, recovery factor increasing, drilling costs decreasing. Technological development concept consists of the most suitable technologies that are being developed in Gazpromneft. Description of some key technologies was made in this section as well. To solve challenges concerned with Achimov reserves localization some project were started, such as «object-oriented approaches for seismic interpretation», «approaches for petrophysical modelling and logging interpretation of thin interlaminated Achimov deposits». The prospective technologies for recovery factor increasing are «stimulated reservoir volume creation» and «miscible gas injection». Drilling costs decreasing will be achieved with optimized well designs and new materials. For correct technologies implementation for different Achimov deposits a special project was started that identifies the degree of different reservoirs similarity according to their accommodation space conditions and production performance.

Based on results of this work some technological projects were started that will give solutions for Achimov technological challenges.

References

1. Yakovlev V.V., Khasanov M.M., Prokofʹev D.O., Shushkov A.V., Technological development in Upstream Division of Gazprom Neft PJSC (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 12, pp. 6–10.

2. Belyakov E.O., Teploukhov V.M., Using a stochastic model of the pore space connectedness for describing filtration-capacitive properties of Priobskoye field AS9-12 layer (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2010, no. 12, pp. 34–38.

3. Fattakhov E., Timirgalin A., Zhukov V. et al., Approaches for petrophysical modelling and logging interpretation of thin laminated Achimov deposits reservoir (In Russ.), SPE 191693-18RPTC-MS, 2018.

4. Glavnov N.G., Kuntsevich V.V., Vershinina M.V. et al., EOR miscible gas project in oil-gas condensate field (In Russ.), SPE 187858-RU, 2017

5. Nenasheva M.G., Okunev M.V., Sleta N.V. et al., The best practices and approaches for replication of Achimov formation development technologies (In Russ.), SPE-191473-18RPTC-RU, 2018.

The rapid development of drilling and completion of horizontal wells (HW), as well as the need for successful selective well interventions requires the growth of informativeness of field geophysics to meet the needs of production. The greatest difficulty in conducting geophysical logging in the area of development control is caused by the non-uniform flow pattern in the HW and the lack of effective methods for delivering equipment to the bottom hole of the HW. Currently, the standard short-term field geophysical logging technology in horizontal wells has been successfully applied to the assets of Gazprom Neft. The technology has been modified for different types of wells both in terms of the research tool, and in terms of delivery technologies and feed-in inducing methods. A further increase in the effectiveness of the geophysical logging in HW, including multilateral HW and multi-fractured HW (MFHW), is associated with the transition from the usual methods of standard one-time logging to stationary distributed or point-distributed monitoring of the inflow / intake profile of horizontal wells. The main stationary monitoring systems, such as fiber optic systems for temperature (DTS) and acoustics (DAS) and point-distributed indicator studies, have already been tested in the first wells of the Company. In order to be able to use these systems on a wide range of wells, the methodological and technological component of research by these systems is currently being developed.

The article presents recommendations of Gazprom Neft experts to increase the informativeness of research of HW and MFHW and minimize the risk of an accident during the downhole operations, as well as conclusions regarding the informativeness and effectiveness of new methods for remote monitoring of low permeability formation in wells with complex completion based on the results of testing and implementation of stationary monitoring systems in the Company.

References

1. Ipatov A.I., Kremenetskiy M.I., Kaeshkov I.S., Experience in the application of distributed fiber optic thermometry for monitoring wells in the company Gazprom Neft (In Russ.), PRONEFTʹ. Professionalʹno o nefti, 2017, no. 3, pp. 55–64.

2. Kremenetskiy M.I., Ipatov A.I., Statsionarnyy gidrodinamiko-geofizicheskiy monitoring razrabotki mestorozhdeniy nefti i gaza (Stationary hydrodynamic-geophysical monitoring of the development of oil and gas fields), Moscow – Izhevsk: Publ.of Institute of Computer Science, 2018, 796 p.

3. Ipatov A., Kremenetskiy M., Lazutkin D. et al., Flow velocity estimation in horizontal oil wells using the method of thermal flowmeter based on the fiber-optic distributed permanent monitoring system, SPE-191557-18RPTC-MS, 2018.

For efficient oil and gas saturated reservoirs management (from waterflood induced fractures identification to water flooding system optimization of mature fields) it is often needed to promptly evaluate interwell hydrodynamics interaction. 3D reservoir simulation is of highly time consuming and it requires computational resources to evaluate required parameters, unlike semi-analytic models. In this paper, we describe various types of CRM-based (Capacitance Resistive Model) semi-analytic models, their features and restrictions, results of their practical application in well interference evaluation within a real field, and applicability criteria.

In this paper, we offer a new approach to hydrodynamic well interference evaluation based on the CR-model and its modifications, adapted for application on the real reservoir. A CR-model allows for determination physical parameters describing the fluid flow, requiring minimum resources and input data (flowrate, bottom-hole pressure, injection capacity, hole location, porosity and permeability). However, these models have notable applicability limitations, obstructing their implementation for work with field data. We made an analysis of application various types of CRM to field data, analyzed their efficiency for various problems and possibilities to avoid limitations that hamper the implementation of semi-analytic models for actual field data. We analyzed potential of various modifications of CR-models, differing by the amount of recorded events that affect the fluid flow, complexity and number of objective variables. Straightforward models exploit only flow rate and injection rate as input data. Ones that are less straightforward also use the bottom-hole pressure and, if needed, well shut down tracking. We estimated training speed with a training data sample for each modification till convergence and relative prediction error with test data are achieved. For this purpose we selected several cases with real field data with a variety of following parameters: number of wells, training time, number of a well’s startups and shutdowns, along with noise grade. Application area was evaluated for each modification of a CR-model.

References

1. Yousef A.A., Gentil P.H., Jensen J.L., Lake L.W., A capacitance model to infer interwell connectivity from production and injection rate fluctuations, SPE 95322-MS, 2006.

2. Sayarpour M., Zuluaga E., Kabir C.S., Lake L.W., The use of capacitance–resistance models for rapid estimation of waterflood performance and optimization, Journal of Petroleum Science and Engineering, 2009, V. 69(3-4), pp. 227–238.

3. Muskat M., The flow of homogeneous fluids through porous media, McGraw-Hill, New York, 1937.

4. Buzinov I.U., Umrikhin S.N., Issledovanie neftyanykh i gazovykh skvazhin i plastov (Investigation of oil and gas wells and reservoirs), Moscow: Nedra Publ., 1984, 269 p.

5. Savitzky A., Golay M.J., Smoothing and differentiation of data by simplified least squares procedures, Analytical chemistry, 1964, V. 36(8), pp. 1627–1639.

6. Kaviani D., Jensen J.L., Lake L.W., Estimation of interwell connectivity in the case of unmeasured fluctuating bottomhole pressures, Journal of Petroleum Science and Engineering, 2012, V. 90, pp. 79–95.

This paper presents a formalized method of testing hydraulic fracturing simulators for a planar fracture, validating the robustness of the implemented physical and mathematical models. In this set of tests, the main accent is made on implementation of the basic laws of hydraulic fracturing: equations of elasticity, the law of mass conservation, the equation of lubrication, leak-offs model, fracture propagation criterion. All tests are done with the dimensionless parameters of the hydraulic fracturing. Scaling of the equations leads to the universality of the given tests. Dimensionless parameters determine fracture form, fracture fluid effectivity and the fracture propagating regime. Different practical cases with the same dimensionless parameters have the same scaled parameters. Therefore, the test into the dimensionless parameters is more universal, than ordinary practical case. Also, the modeling of the different practical cases with the same dimensionless parameters helps to determine value of relative errors of the calculation scheme. Verification of the mathematical model is carried out both by comparison with known analytical and semi-analytical solutions for specific cases (Radial, PKN models) and by compliance with fundamental physical laws. The fracture leak-offs and fracture fluid effectivity is validated by the well-known Nolte-function, which represented in the dimensionless form. This set of tests is the basis for a universal system of fracture simulator tests and will allow to objectively compare existing commercial and non-commercial simulators with existing benchmarks, as well as with each other.

References

1. Khasanov M.M., Paderin G.V., Shel' E.V. et al., Approaches to modeling hydraulic fracturing and their development (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 2, pp. 37–41.

2. Irwin G.R., Fracture mode transition for a crack traversing a plate, Journal of Basic Engineering, 1960, V. 82, no. 2, pp. 417–423

3. Shel E. et al., Retrospective analysis of hydrofracturing with the dimensionless parameters: Comparing design and transient tests, SPE 191707-18RPTC-MS, 2018.

4. Perkins T.K. et al., Widths of hydraulic fractures, Journal of Petroleum Technology, 1961, V. 13, no. 9, pp. 937–949.

5. Economides M.J. et al., Reservoir stimulation, Englewood Cliffs, NJ: Prentice Hall, 1989, pp. 356–358.

As the petroleum industry development trend suggests by 2025 a significant part of Gazprom Neft’s hydrocarbons production will be provided by oil and gas condensate fields with oil rims and complex geological structure. By that time, the share of production from green fields will reach 50%. Given the complexity of such fields, the success of development projects will depend on the quality of consideration and efficiency of interrelated solutions for both field development and infrastructure facilities configuration.

This paper presents the experience in building a full-scale integrated model of a large oil-gas-condensate field, which includes models of oil rims for the main reservoirs, models of wells and downhole equipment, model of the fluid gathering and transportation system including the main transfer pumping station, and model of the gas reinjection system including the gas treatment facility compressor station.

The goal of the work is to find a balanced solution for oil well operation parameters taking into account the constraints imposed by the infrastructure. Integrated modeling is aimed at improving the project planning and production profile prediction quality by combining the models of the reservoir, wells, fluid gathering networks and surface infrastructure facilities into a single generic model. Development and implementation of this model that considers together the processes occurring in the reservoir and the surface networks, and takes into account infrastructure facilities’ operation constraints such as velocity of gas-liquid mixture in production tubing and in flowlines of the oil and gas gathering systems, constraints existing in the Gas Treatment Facility and Oil Treatment Facility, loop lines and bridges in pipeline systems, ensures higher quality of project decisions. The working platform for the integrated model is the RESOLVE software package in combination with the GAP, Prosper and tNavigator simulation products.

References

1. Ushmaev O.S., Apasov R.T., Chameev I.L. et al., Integrated modelling approach as estimation tool for well regimes and gathering network impact on oil rim development (In Russ.), SPE 182007, 2016 .

2. Ushmaev O.S., Chameev I.L., Bazhenov D.Yu., Artamonov A.A., EOR gas re-injection optimization at an oil, gas and condensate field (In Russ.), PRONEFT''. Professional'no o nefti, 2016, no. 2, pp. 54–60.

3. Povyshev K.I., Vershinin S.A., Vernikovskaya O.S., Integrated model "Reservoir - Well - Infrastructure" and its opportunities (In Russ.), PRONEFT''. Professional'no o nefti, 2016, no. 2, pp. 48–53.

Gas breakthrough during development of oil rim is one of the main factors leaded to low sweep efficiency and low economic efficiency. There are lots of proposals to limit gas breakthrough during oil rim development by injection water or heterogeneous systems to create gas-prevention screen near gas-oil contact. Such enhanced oil recovery method for oil rims now is underexplored not only theoretically but also practically. Also there is not technic-and-economic evaluation of this method and gas-prevention screen configuration is not calculated but supposed. At the same time blocked pattern of gas-prevention screen configuration depending on vertical anisotropy of the reservoir. The main goal of the present work is efficiency estimation of gas breakthrough limitation technology and determination of geological conditions at which using of such technology is reasonable. Production profiles are calculated by numerical simulation. Also numerical simulation is used to determine blocked pattern of gas-prevention screen in reservoir formed by water or heterogeneous systems injection. For every geological conditions optimal placing and injected amount is determined, production profile with gas-prevention screen is compared to production profile without application any enhanced oil recovery technology. Also technic-and-economic evaluation and limits to applicability of discussed method is presented. Efficiency criterion is NPV. Results of the present work can be used for oil rim’s development technology screening.

References

1. Patent no. 2148154 RF, Method of narrow oil fringes development, Inventors: Strukova N.A., Berlin A.V.

2. Severov YA.A., Povyshenie ehffektivnosti razrabotki mestorozhdeniy uglevodorodov pri nalichii yavleniy konusoobrazovaniya (Improving the efficiency of the development of hydrocarbon deposits in the presence of phenomena of coning): thesis of candidate of technical science, Moscow, 2006.

3. Butler R.M., Horizontal wells for the recovery of oil, gas and bitumen, Petroleum Society of CIM, Monograph no. 2, 1994.

4. Homsy G.M., Viscous fingering in porous media, Ann. Rev. Fluid Mech., 1987, no. 19, pp. 271–311.

5. Saffman P.G., Viscous fingering in Hele-Shaw cells, J. Fluid Nech., 1986, V. 173, pp. 73–94.

6. Khasanov M.M., Ushmaev O.S., Samolovov D.A. et al., Estimation of cost effective oil thickness of oil rims developed with horizontal wells (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2013, no. 12, pp. 44–47.

The article is devoted to the formation of a conceptual approach to the development of floating oil fringe of the Valanginian deposits of the Yaro-Yahinskoye field through the usage of horizontal and multilateral wells. A feature of the geological structure of the main productive deposit of the Yaro-Yahinskoye field

(BT7-8) is a layered reservoir with high heterogeneity of the filtration properties due to the features of formation (fluvial delta). Secondary post sedimentation processes such as leaching of feldspar complicates the existing geology, which leads to the formation of lateral anisotropy of the reservoir properties.

The adopted design solution for the development of this oil fringe is the drilling of horizontal wells according to the selective system. Development of the reservoir is on depletion mode with a fountain method of wells operation. Drilling and development of horizontal wells at the stage of pilot works showed the level of the starting water cut is much higher than planned, which led to the adjustment of both the geological structure of the reservoir in terms of saturation, and to the adjustment of the strategy of horizontal wells drilling. Oil saturated reservoir interval of the oil rim divided into three saturation regions: limit oil saturation zone, the zone of transient saturation and the limit zone of water saturation. Controlling factors in the spread of these zones are the geological features of the reservoir BT7-8: contrast of layers properties, the reservoir structure (hypsometric position of the reservoir) and the leaching of feldspars. The forecast of the influence of the first two factors, taking into account the high density of exploration drilling, is quite high in contrast to the last factor of secondary changes in the formation due to the low characterization with the core in the area of the productive formation. In this regard, the strategy of drilling horizontal wells has been adjusted. It was offered to apply MDT technology and sampling to correct drilling corridor of horizontal wells. In addition, to reduce the risks of accelerated formation of water and gas cones in the floating oil fringe of the BT7-8 layer of the Yaro-Yahinskoye field, it is proposed to use drilling of multi-hole wells, which will also increase the oil production and reduce the working depression on the reservoir.

Standard techniques of geological data analysis and further static modelling include restoring of sedimentary environment of rocks and prediction of reservoir properties according to sedimentary facies distribution. In case of carbonate rocks, accuracy of reservoir properties prediction in static and hence dynamic model is not enough for confident production forecast. One of the features of carbonate rocks is a significant alteration of initial sedimentary reservoir properties by secondary transformations of rocks. Specialists from Gazpromneft NTC has developed and successfully applied a standardized algorithm for the study of carbonate reservoirs. It includes the analysis of petrographic studies, work with core data, interpretation and analysis of seismic data and as a result the creation of a conceptual geological model. The aim of this work was to create a reliable geological model for confident forecasting of new wells productivity. Key objectives for carbonate reservoirs are identification of main drivers of reservoir productivity and their genetic interpretation and prediction of its distribution in a static and dynamic model. The present paper describes integrated multidisciplinary approach to the reservoir study and prediction of properties of carbonate reservoirs on example of one of the fields in the Middle East. The accuracy of the proposed approach for properties distribution is confirmed by the results of new wells drilling and testing.

References

1. Geology of Iraq: edited by Jassim S.Z., Goff J.C., Dolin, Prague and Moravian Museum, Brno, 2006, 344 p.

2. Idrisova S.A., Tugarova M.A., Stremichev E.V., Belozerov B.V., Digital core. Integration of carbonate rocks thin section studies with results of routine core tests (In Russ.), PRONeft', 2018, no. 2, pp. 36–41.

Serbian oilfield Kikinda on its last development stage, has got the new impulse for the lower object based on the results of the new well drilled. This well contain a large set of data, e.g. core analysis, special well logging complex etc. According to the core, the origin of the studied sediments has been established as a “lake” turbidities with all the textural characteristics of classic turbidities. Oilfield is located in Pannonian basin which was isolated local system, with small depths during the time of reservoir formation. Hypsometric position and seditmentation rate are main difference between classic turbidities and studied turbidities. The thin-bedded reservoir, in the presence of layers of poorly lithified sandstones, required the development of a special interpretation method and the presence of special logging, which was suggested by the authors as one of the ways to solve this important problem. Author's interpretative algorithm was formalized in specialized software, and allows on-the-fly execution of decisions for the new wells during the operational work. After reinterpretation of the majority of the wells and reserves estimation, based on the new geological model and taking into account the results of sedimentological analysis, the new drilling plan was developed and now it is on a stage of active implementation.

References

1. Gogic A., Milei E., Zhukovskaia E., Facial model as a key for successful exploitation: case study, Pannoninan basin, Late Miocene, Proceedings of 20th International Sedimentological Congress “A sedimentary journey through 3 billion years in the new world”, 2018, V. 2, p. 870.

2. Zhukovskaia E., Olneva T., Turbidites of epicontinental basins, Proceedings of XVII Serbian Geological Congress, 2018, pp. 226–232.

3. Thomas E.C., Stieber S.J., The distribution of shale in sandstone and its effects upon porosity, In Trans. 16th Annual Logging Symposium of the SPWLA, 1975, рр. 6–7.

4. Klein J.D., Martin P.R., Allen D.F., The petrophysics of electrically anisotropic reservoirs, The Log Analyst, 1997, May-June, рр. 25–36.

and production can become a major problem during the development of weakly consolidated reservoirs. Sand control methods include various downhole filters such as slotted liners, wire wrapped screens, gravel packs, etc. However, only a few methods are capable to evaluate and predict the effectiveness of the sand control method depending on the geological and mechanical parameters of the reservoir.

The article presents a new model of multi component suspension that can be used to estimate the additional pressure drop due to the presence of gravel filter. The constructed model describes fluid flow with solid particles of different sizes in a porous medium. The model is based on the conservation of mass equations for individual phases in multiphase flow. The phases considered in the model include carrier fluid, mobile and trapped solid particles. Empirical relationships of suspension viscosity on the concentration of solid particles, the dependence for the particles trapping probability, and the formula connecting the permeability and the porosity of a gravel filter were used as constitutive relationships. In contrast to the previously presented models, in this article, particles of different sizes are considered as separate phases, so that particle size distribution is taken into account. Adaptation can be performed by comparing the model calculations with the results of numerical experiments based on the discrete element method or with field data. The model, set up by the first method, can be used to estimate the changes in the parameters of a gravel filter in time, based solely on the particle size distribution of the formation rock. The data obtained from the operation allows improving this evaluation.

In general, the presented model can be used to calculate the dynamic changes in the skin factor of a well equipped with a gravel filter, and also potentially to optimize the sizing criteria for gravel packs.

References

1. Saucier R., Considerations in gravel pack design, Journal of Petroleum Technology, 1974, V. 26, no. 2, pp. 205–212.

2. Unneland T., An improved model for predicting high-rate cased-hole gravel-pack well performance, SPE 54759-MS, 1999.

3. Furui K., Zhu D., Hill A., A new skin factor model for gravel-packed completions, SPE 90433-MS, 2004.

4. McDowell-Boyer L., Hunt J., Sitar N., Particle transport through porous media, Water Resourses Research, 1986, V. 22, no. 13, pp. 1901–1921.

5. Boronin S.A., Osiptsov A.A., Tolmacheva K.I., Multi-fluid model of suspension filtration in a porous medium, Fluid Dynamics, 2015, V. 50, no. 6, pp. 759–768.

6. Sacramento R., Yang Y., You Z. et al., Deep bed and cake filtration of two-size particle suspension in porous media, Journal of Petrolium Science and Engineering, 2015, V. 126, pp. 201–210.

7. Lezhnev K., Application of discrete element method for modelling sand control systems (In Russ.), SPE 191525-18RPTC-MS, 2018.

8. Coelho D., Thovert J.-F., Adler P., Geometrical and transport properties of random packings of spheres and aspherical particles, Physical Review E, 1997, V. 55, no. 2, pp. 1959–1978.

9. Rong L., Dong K., Yu A., Lattice-Boltzmann simulation of fluid flow through packed beds of uniform spheres: Effect of porosity, Chemical Engineering Science, 2013, V. 99, pp. 44–58.

10. Osiptsov A., Hydraulic fracture conductivity: effects of rod-shaped proppant from lattice-Boltzmann simulations and lab tests, Advances in Water Resources, 2017, V. 104, pp. 293–303.

11. Van den Hoek P., Geilikman M., Prediction of sand production rate in oil and gas reservoirs, SPE 84496-MS, 2003.

12. Wang J., Walters D., Wan R., Settari A., Prediction of volumetric sand production and wellbore stability analysis of a well at different completion schemes, The 40th U.S. Symposium on Rock Mechanics (USRMS), Anchorage, Alaska, USA, 05-842 ARMA Conference Paper, 2005.

13. Sharma M., Wang H., A fully 3-D, multi-phase, poro-elasto-plastic model for sand production, SPE 181566-MS, 2016.

14. Wu C., Sharma M., Fuller M., Mathis S., Estimating sand production through gravel packs, SPE 189481-MS, 2018.

Petroleum companies are starting to make greater focus in their portfolios of promising assets on complex projects with a high level of uncertainty with regard to oil reserves and geology. Successful delivery of such projects requires new approaches to be used. One of such approaches involves employment of modular technologies in field infrastructure development that enable effective performance in the face of geology- and production-related uncertainties. The article describes the basic principles of modular strategy that have been formulated and put to use by Gazprom Neft: modular supply of ready-to-use infrastructure elements; harmonization of modular solutions; scalability – customization of a technology based on the changing operating conditions as a result of increase in well production rate and variation of physical and chemical properties of the product; ‘mobility’; and transformation of business processes with the help of modular technologies. Gazprom Neft has traveled its own path in the field of modular solutions and used the lessons learned to formulate these basic principles. As of today, the Company has designed structural and process solutions for modular oil treatment plants and mobile systems to be used at the pilot stage. In 2018, the Company started trials of these solutions at its major projects alongside with transformation of the plant design, purchase and manufacture and field development (early oil) business processes with the help of modular solutions. Only concerted delivery of the above principles will secure: short-term launch of projects due to reduced time required to design and build facilities; optimization of capital expenditures (if expected production rate is not confirmed – disassembly of elements and modules and their shipment to a different project) and minimization of venture capital in the context of high geological uncertainty; extraction of early oil; increased NPV at marginal projects.

References

1. Ismagilov R.R., Present day trends in oil and gas engineering (In Russ.), Neft'. Gaz. Novatsii, 2017, no. 9, pp. 25–30.

2. Liker J.K., The Toyota Way: 14 management principles from the world's greatest manufacturer, McGraw-Hill, 2004, 352 p.

Hefty dose of new projects of company depend on basic data fullness and construction of permanent facilities planning accuracy in an early stage. Potentially productive license blocks are characterized by extremely inhomogeneous geology what can lead to problems in engineering process, construction of works and also can lead to period and cost increase for the purpose of inadequate attention on the stage of conceptual engineering. Creating a module for optimal allocation of infrastructures sites and linear facilities routes allows undertake the analysis, look for stable and most effective solution under terminated basic data. In case of appearance new information, it allows recalculate and give a recommendation about necessity of entering of adjustments in previously stated solutions.

Result of current work, as part of engineering design, is prototype module for information system ERA:ISKRA. Analysis and introduction topographical data best practices, and also parallel appliance of cost engineering module, allow develop optimization algorithms, which taking into account both technologic facilities parameters and differences in cost of constructing in diverse terms. Module considers factors such as: terrain relief, hydrologic and topographic special aspects of construction other facilities existent in this zone.

Developed algorithms for finding optimal trajectory allowed discount cost of communications corridors by 10 per cent in comparison with projected manually. Achieved result reached due to: decreasing summary length of net, pipeline placement in most optimal conditions for building (minimization bogs crossing), decreasing pipeline diameters (decreasing summary length of net and the difference in elevation).

References

1. Ismagilov R.R., Maksimov Yu.V., Ushmaev O.S. et al., Integrated model for complex management of reservoir engineering and field construction (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2014, no. 12, pp. 71–73.

2. Vlasov A.I., Mozhchil' A.F., Technology overview: from digital to intelligent field (In Russ.), PROneft', 2018, no. 3(9), pp. 68–74.

3. Khamidullin R.D., Ismagilov R.R., Kan A.V. et al., The choice of regional infrastructure development strategy in conditions of production uncertainty using software ERA:ISKRA (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 12, pp. 64–67.

4. Ismagilov R.R., Panov R.A., Gil'mutdinova N.Z. et al., Economic-mathematical modelling of optimal pipeline configuration (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 12, pp. 60–63.

5. Lotarev D.T., The Steiner problem for a transportation network on a surface specified by a digital model (In Russ.), Avtomatizatsiya i telemekhanika = Avtom. Telemekh., 1980, no. 10, pp. 104–115.

6. Batrashkin V.P., Ismagilov R.R., Panov R.A. et al., The integrated conceptual design as a tool of systematic engineering (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 12, pp. 80–83.

This article continues the series of publications devoted to the problem of ensuring iceberg security during exploration drilling in the waters of the Arctic seas. During 2012-2017 Russian Oil Company Rosneft together with Russian Arctic and Antarctic Research Institute and Arctic Research Center (Rosneft R&D institute) conducted 12 complex expeditions both in the seasons of maximum ice cover and open water in the seas of the Russian Arctic. The research was focused on the new environmental (oceanographic/ice/etc.) data gathering and testing of iceberg towing technologies.

Iceberg detection is one of the most challenging topics in the conditions of polar night and bad weather. Ice, wind and fog may significantly decrease possibilities of detection that might be crucial for ice defense. Different means and equipment used to detect ice features might be used but unfortunately there is no “magic pill” for all cases.

The paper presents generalized information on the morphometry and dynamics of icebergs in the southwestern part of the Kara Sea, as well as results of the applicability analysis of different means of icebergs detection. These data make it possible to formulate the requirements for the iceberg detection block of the optimal ice defense system for arctic conditions.

References

1. Buzin I.V., Mironov E.U., Sukhikh N.A. et al., Investigation of drift of the ice features on the Russian Arctic Offshore with the help of automatic radio beacons based on the ARGOS satellite system (In Russ.), Nauchno-tekhnicheskiy vestnik OAO “NK “Rosneftʹ”, 2016, no. 4, pp. 4–9.

2. Abramov V., Atlas of Arctic icebergs, Backbone Publishing Company, 1996, 70 p.

3. Bychkova I.A. Smirnov V.G., Use of satellite data for detecting icebergs and evaluating the iceberg threats, Ice and snow, 2018, no. 4, pp. 537–551.

4. Smirnov V.G., Bychkova I.A., Satellite monitoring of ice features to ensure safety of offshore operations in the Arctic seas, Izvestiya, Atmospheric and Oceanic Physics, 2015, V. 51, no. 9, pp. 935–942.

5. Sochnev O.Ya., Kornishin K.A., Tarasov P.A, Sal'man A.L., Glazovskiy A.F., Lavrent'ev I.I., Efimov Ya.O., Mamedov T.E., Studies of glaciers in the Russian Arctic for safe marine operations in iceberg waters (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 10, pp. 92–97.

6. Pashali A.A., Kornishin K.A., Tarasov P.A., Efimov Ya.O., Nesterov A.V., Chernov A.V., Buzin I.V., Svistunov I.A., Maksimova P.V., Iceberg towing as a technology for its drift change to ensure safe Arctic development (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 11, pp. 36–40.

The object of modeling was the horizon, which combines a group of productive layers of the Barremian age of a large oil and gas condensate field of the Surgut Arch. This horizon has more than 40 years of exploration and is characterized by a high amount of remaining resources. The oil fringe which has less than 10 m high in most cases has contact with water or gas and also high degree of discontinuity of lithology are determined heavy conditions from the first steps of exploration. The interpretation of well logs of transit wells shows the high level of resource discontinuity which has wide zones of advent bottom and injected water. The research of the geological construction was made for successful arrangement planning to enhance oil recovery and involving non-draining resources.

The results of research of the productive horizon conditions are shown in present paper. The four sand layers were detached in more than 8 thousands wells by using the results of cycling research. Facies typing of the deposits was made and after verified with well and seismic data, which have allowed establishing the vision of the environments which have been made by using the core. Furthermore the position of reservoir rocks and their qualitative characterization were made. Reservoir properties were examined with their environments. The new petrophysical functions were suggested for the certain layers and zones. The geological model was developed; the new parameters of permeability were recalculated for the experimental sector. Different types of classification petrophysical characteristics of the reservoir rocks were studied. The results will be a base for hydrodynamic modeling.

References

1. Atlas litologo-paleogeograficheskikh kart yurskogo i melovogo periodov Zapadno-Sibirskoy ravniny i Ob"yasnitel'naya zapiska k Atlasu (Atlas of lithologic and paleogeographic maps of Jurassic and Cretaceous periods of the West Siberian Plain and the Explanatory note to the Atlas): edited by Nesterov I.I., Tyumen': Publ. of ZapSibNIGNI, 1976, 85 p.

2. Alekseev V.P., Atlas fatsiy yurskikh terrigennykh otlozheniy (uglenosnye tolshchi Severnoy Evrazii) (Atlas of Jurassic clastic sediments facies (coal-bearing strata of Northern Eurasia)), Ekaterinburg: Publ. of USGU, 2007, 209 p.

3. Baraboshkin E.Yu., Prakticheskaya sedimentologiya. Terrigennye kollektory (Practical sedimentology. Terrigenous reservoirs), Moscow: GERS Publ., 2011, 152 p.

4. Geologiya dlya neftyanikov (Geology for oilmen): edited by Malysheva N.A., Nikishina A.M., Moscow – Izhevsk: Publ. of Institute of Computer Science, 2008, 360 p.

5. Mangazeev V.P., Belozerov V.B., Methodology of representing lithological and facial features in a digital geological model (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2006, no. 5, pp. 66–70.

Unconventional hydrocarbons include resources located in complex geological conditions in "unconventional" traps that require the use of new methods of exploration, production, processing and transportation. The separation of Domanic deposits as an oil source suite and lithological and formational features of the section makes it possible to consider them as a target for the search for unconventional hydrocarbon accumulations.

On the territory of the Volga-Ural oil and gas province Domanic deposits are widely developed as part of the Upper Devonian-Tournaisian sedimentary complex. They are characterized by large lithological-facies diversity; they are associated with various traps of hydrocarbons, both traditional and non-traditional. Domanicoid sediments of Buzuluk petroleum region have been studied very unevenly by drilling. Domanic facies were opened by drilling under the study of more ancient Devonian horizons. In the region Middle Frasnian-Tournaisian deposits of Domanic type are the most drilled out within the territory of traditional terrigenous Devonian deposits. In the rest of the territory, drilling knowledge is significantly lower. Troitskoye field is the first oil field in domanicoid sediments in Orenburg region placed on the state balance. The development of hydrocarbon deposits of Domanic type is hitherto not possible. Of particular interest is the study of fractured low-permeability reservoirs, which include Domanic deposits. The use of CDP 2D seismic survey with the use of innovative methods will help to solve the issues of proper understanding of the basic problems of formation, migration and accumulation of oil and search for movable hydrocarbons directly in Dominic sediments.

References

1. Zaydel'son M.I., Vaynbaum S.Ya., Koprova N.A. et al., Formirovanie i neftegazonosnost' domanikoidnykh formatsiy (Formation and oil and gas potential of Domanis rocks), Moscow: Nauka Publ., 1990, 79 p.

2. Kiryukhina T.A., Fadeeva N.P., Stupakova A.V. et al., Domanik deposits of Timano-Pechora and Volga-Ural basins (In Russ.), Geologiya nefti i gaza = The journal Oil and Gas Geology, 2013, no. 3, pp. 76-87.

3. Neftegazoobrazovanie v otlozheniyakh domanikovogo tipa (Oil and gas formation in the Domanik deposits), edited by Neruchev S.G., Leningrad: Nedra Publ., 1986, 247 s.

4. Prishchepa O.M., Integrated method of oil and gas quantitative evaluation in petroleum accumulation zones (In Russ.), Neftegazovaya geologiya. Teoriya i praktika, 2011, V. 6, no. 4, URL: http://www.ngtp.ru/rub/6/44_2011.pdf

5. Navrotskiy A.O. et al., Geologicheskiy otchet o rezul'tatakh rabot, vypolnennykh po ob"ektu “Seysmorazvedochnye raboty na domanikoidnye otlozheniya Buzulukskoy vpadiny” (Geological report on the results of works on the object "Seismic exploration of the Domanicoid deposits of the Buzulukskaya depression"), Moscow: Publ. of Moscow branch of Rosgeolfond,

VNIIGeosistem, 2016, 4648 p.

6. Chirkin I.A., Izuchenie ob"emnoy struktury treshchinovatosti neftenasyshchennykh otlozheniy na Severo-Dem'yanskom neftyanom mestorozhdenii Tyumenskoy oblasti metodom seysmolokatsii bokovogo obzora (Study of the volume structure of fracturing of oil-saturated sediments in the North-Demyansk oil field of the Tyumen region using side-seismic seismology), Moscow, 1999: Publ. of Rosgeolfond, 36 p.

7. Chirkin I.A., Zhukov A.S., Volkov A.V., Opredelenie treshchinovatosti produktivnykh tolshch rifeya metodom SLBO na vostoke-severo-vostoke Kuyumbinskogo i severo-severo-zapade Tersko-Kamovskogo litsenzionnykh uchastkov (metodicheskoe soprovozhdenie polevykh rabot, obrabotka i interpretatsiya materialov) (Fracture determination of the Riphean productive strata by the side-seismic seismology method in the east-northeast of Kuyumbinsky and north-north-west of the Terek-Kamovsky license areas (methodological support of field work, processing and interpretation of materials)), Moscow, 2007: Publ. of Rosgeolfond, 153 p.

The high price of traditional well construction (production casing ∅168 mm) does the development system non-commercial for residual recoverable reserves on Perm oilfields. Reduction of construction costs on 25% was provided by reducing the casing string diameter and load capacity of drilling rig.

This article presents an experience and results of slim hole construction and technical – technological solutions for additional reduction of work time and risk minimization. Positive results were confirmed by dynamics of slim holes construction commercial speed. Technological solution, which lets to reconstruct the slim hole by drilling rat hole, was reviewed in article. There are multilateral slim hole drilling results presents.

At present time project development system with using deviated slim hole was implemented on Bashkirian object Gondyrevskoe oilfield, were drilled 30 slim holes during 2011-2017 (51% of producing well stock) with initial flow rate 7.8 t/d. The results were become the basis for further replication it technology. Medium term, slim hole drilling volume will be expanded on Bashkirian, Werenian, Kashirian-Werenian objects on Baklanovskoye, Batyrbayskoye, Krasnoyarsko-Kuyedinskoye, Kokuyskoye, Shagirtsko-Gozhanskoye, Nozhovskoye, Shumovskoye oilfields. Pay attention to significant reduction of slim hole construction costs, which was reached by new technology implementation, was decided to revise criteria of minimum profitable flow rate and recoverable reserves for different well design. Also was decided to examine the technical – technological aspects of slim hole drilling for deeper horizons (Tulskian-Bobrikovskian, Tournaisian).

References

1. Meshcheryakov K.A., Yatsenko V.A., Il'yasov S.E., Okromelidze G.V., Drilling of small diameter wells as a way to reduce costs in the construction of development and exploratory wells (In Russ.), Territoriya NEFTEGAZ, 2013, no. 10, pp. 26–29.

2. Meshcheryakov K.A., Okromelidze G.V., Yatsenko V.A. et al., The results of construction of the first small diameter multilateral well in LUKOIL PJSC (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 10, pp. 47–49.

3. Meshcheryakov K.A., Il'yasov S.E., Okromelidze G.V., Yatsenko V.A., Drilling of the sidetrack from the small diameter well (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 8, pp. 45–47.

4. Kadyrov A.Kh., Glukhoded A.V., Dual completion units for small diameter wells (In Russ.), Inzhenernaya praktika, 2017, no. 6, pp. 4–11.

5. Malikov M.M., Adoption of dual injection technology in wells with s

The object of the study is a downhole assembly with a steered downhole diverting motor. While drilling deep oil and gas wells their profile should ensure minimum resistance forces to the drill string movement. One of the options is a profile with several sections of deviation angle setting by a large radius alternating with sections of stabilization. To increase the precision of the set radius realization there have been suggested the downhole assemblies providing a contact of supporting elements with the well walls at four points. At rotating such assembly in the deviated well a dynamic interaction of its elements with the wellbore wall might occur there. To prevent such situation it is necessary to create the appropriate gaps, which are designed using a special technique. The study performed enables to choose an assembly based the downhole diverting motor of diameter 172 mm with the angle of obliquity 1o, 1.25o and with drilling bits 215.9 and 220.7 mm to achieve the designed radius of the deviation angle setting within 400-800 m. The assemblies proposed can provide a maximally precise realization of the set well inclination radius without a dynamic interaction of its elements with the well walls. This will enable to reduce a number of operations in correction of the borehole trajectory and quality.

References

1. Povalikhin A.S., Kalinin A.G., Bastrikov S.N., Solodkiy K.M., Burenie naklonnykh, gorizontal’nykh i mnogozaboynykh skvazhin (Directional, horizontal and multihole drilling), Moscow: Publ. of TsentLitNefteGaz, 2011, 647 p.

2. Grechin E.G., Dolgushin V.V., Pyal'chenkov V.A. et al., Designing the downhole drill string assembly with motor-deflector with four-point pattern of its interaction with borehole walls (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 9, pp. 82–85.

The paper presents factors that reflect drilling effectiveness such as non-productive time of well construction and time spent on mechanical drilling and scheduled round trips. Non-productive well construction time for directional drilling at a field usually accounts for 3.2 % of the total construction time. The time spent on mechanical drilling and scheduled round trips using rotary steerable systems, depending on the interval subjected for drilling, is reduced. That increases the average mechanical drilling speed by 8–40 %, which allows drilling wells ahead of the planned schedule by 7 days or more. The shortcomings of the existing Russian and foreign analogues of rotary steerable systems are identified. They are caused by incomplete design, low accuracy and imperfect technologies. The design of the bit shaft drive was improved in the developed drilling tool control system through the use of three electric drives with feedback sensors controlled by the electronic module. In order to improve bit positioning accuracy in rotary steerable systems, the design of a drilling tool control system is proposed. The design includes a module for determining spatial position based on a geostationary system and fiber-optic gyroscopes with a closed loop. The drilling tool control system has a modular type, which allows it to be included in various drill string assembly. The prototype of the module for determining the spatial position of the drilling tool control system is studied. During the studies the module was deviated at different angles; the software simulated well deepening, zenith and azimuth angles were measured. The results of studies showed that the absolute measurement errors of azimuth and zenith angles do not exceed 0.5 %.

References

1. Baldenko D.F., Vervekin A.V., Plotnikov V.M., Ways to further improvement of well drilling by downhole drilling motors (In Russ.), Vestnik Permskogo natsional'nogo issledovatel'skogo politekhnicheskogo universiteta. Geologiya. Neftegazovoe i gornoe delo = Perm Journal of Petroleum and Mining Engineering, 2016, no. 19, pp. 165–174, DOI: 10.15593/2224-9923/2016.19.7

2. Zaikin I.P., Pankov M.V., Ismailov N.A., Pushkarev S.V., Rotary controllable system PowerDrive and well log survey system PeriScope operation in horizontal well drilling (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2009, no. 11, pp. 68 –70.

3. Nikolaev N.I., Kozhevnikov E.V., Enhancing the cementing quality of the well with horizontal profile (In Russ.), Vestnik Permskogo natsional'nogo issledovatel'skogo politekhnicheskogo universiteta. Geologiya. Neftegazovoe i gornoe delo = Perm Journal of Petroleum and Mining Engineering, 2014, no. 11, pp. 29–36, DOI: 10.15593/2224-9923/2014.11.3

4. Nutskova M.V., Rudyaeva E.Yu., The effect of water-swellable polymer on well drilling with mud loss (In Russ.), Vestnik Permskogo natsionalʹnogo issledovatelʹskogo politekhnicheskogo universiteta. Geologiya. Neftegazovoe i gornoe delo. = Perm Journal of Petroleum and Mining Engineering, 2018, no. 2, pp. 104–114, DOI: 10.15593/2224-9923/2018.2.1.

5. Patent no. 6158529 USA, Rotary steerable well drilling system utilizing sliding sleeve, Inventor: Dorel ‎A.P.

6. Patent no. 2618535 RF, Method for rotational controlled drilling assembly control with channels with varying fluid flow, Inventors: Uinslou D., Deolalikar N.

7. Patent no. WO2013122603A1, Directional drilling systems, Inventors: Smith R.C., Kanji K.N.

8. Patent no. 2123108 RF, Method of controlling directed drilling of slant wells and device for its embodiment, Inventors: Litvinenko V.S., Kudrjashov B.B., Petrov O.M., Rubinraut A.M.

9. Patent no. 2192535 RF, Hinged sub, Inventors: Baldenko D.F., Vlasov A.V., Mutovkin N.F., Povalikhin A.S., Strel'tsov N.A.

10. Patent no. 2612403 RF, Device for hydromechanical control of directional rotary drilling.

11. Rusinov D.YU., Turbakov M.S., Kunitskikh A.A., Krysin N.I., Study of the reliability of the drilling control system''s deflection unit (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 12, pp. 98–101.

12. Krivoshchekov S.N., Melekhin A.A., Turbakov M.S. et al., Development of a telemetric system for monitoring downhole parameters in the course of wells construction (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 9, pp. 86-88, DOI: 10.24887/0028-2448-2017-9-86-88.

13. Krivoshchekov S.N., Turbakov M.S., Melekhin A.A. et al., Increase in accuracy of well position in space measurements by the telemetry system (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 12, pp. 102–104, DOI: 10.24887/0028-2448-2017-12-102-104.

14. Krysin N.I., Krivoshchekov S.N., Turbakov M.S. et al., Modelling of the well path control process in the telemetry system (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 12, pp. 105–107.

15. Kychkin A.V., Volodin V.D., Sharonov A.A. et al., The synthesis of the hardware and software system structure for remote monitoring and control of the wellbore trajectory while drilling by rotary steerable system (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 11, pp. 128-132.

The unique Arlanskoye oilfield has been successfully developed for 60 years. Since 2010, there has been a growing trend in oil production. Due to the use of high-performance technologies, such as horizontal drilling with multi-stage hydraulic fracturing, proppant and acid fracturing, optimization of reservoir pressure maintenance system, oil production was increased by 17%. Main object development – terrigenous low carbonic thick series is in the final stages of development, at the same time second largest recoverable reserves the Kashirskian-Podolskian object is actively being developed. Actual tasks for further development of the field are localization of current recoverable oil reserves terrigenous low carbonic thick series and the Kashirskian-Podolskian object development system organization.

For the localization of current oil reserves, a geological field analysis with sector geological and hydrodynamic modeling was used. For both objects, taking into account the peculiarities of their geological structure, fluid properties and the current state of development, a detailed development strategy has been developed, which provides systematic application of advanced development methods (horizontal drilling with multi-stage hydraulic fracturing, proppant and acid fracturing), use of differentiated influence system and measures to regulate the development process in the production and injection wells. The implementation of the strategy will increase the oil production field, create an effective development system of Kashirskian-Podolskian object, reduce the amount of produced water at the main object development and improve the production efficiency of the object's reserves.

References

1. Lozin E.V., Razrabotka unikal'nogo Arlanskogo neftyanogo mestorozhdeniya vostoka Russkoy plity (Developing a unique Arlan oil field of the East of the Russian Plate), Ufa: Skif Publ., 2012, 704 p.

2. aymukhametov K.S., Enikeev V.R., Syrtlanov A.Sh., Yakupov F.M., Geologicheskoe stroenie i razrabotka Arlanskogo neftyanogo mestorozhdeniya (Geological structure and development of the Arlanskoye oilfield), Ufa: Publ. of Bashneft', 1997, 368 p.

3. Satarov M.M., Andreev E.A., Klyucharev V.S. et al., Proektirovanie razrabotki krupnykh neftyanykh mestorozhdeniy (Designing the development of large oil fields), Moscow: Nedra Publ., 1969, 238 p.

4. Gabitov G.Kh., Lozin E.V., Designing the development of Arlanskoye oilfield (In Russ.), Neftyanoe Khozyaystvo = Oil Industry, 2005, no. 7, pp. 76-79.

5. Chervyakova A.N., Budnikov D.V., Akhmetzyanov R.V. et al., Vliyanie osobennostey geologicheskogo stroeniya obʺekta KPO Arlanskogo mestorozhdeniya s pelitomorfnymi plastami na nachalʹnye pokazateli raboty skvazhin (The influence of the geological structure of the Kashiro-Podolsk deposits object with pelitomorphic layers of Arlan field on the initial well performance), Collected papers “Aktual'nye nauchno-tekhnicheskie resheniya neftedobyvayushchego potentsiala PAO ANK “Bashneft'” (Current scientific and technical solutions to the oil production potential of Bashneft PJSC), 2016, V. 124, pp.

6. Fedorenko N.V., Lozin E.V., Gareev A.T. et al., Improving production efficiency of multilayer terrigenous Low Carbonic thick series of Arlanskoye oilfield (In Russ.), Neftyanoe Khozyaystvo = Oil Industry, 2018, no. 9, pp. 106–110.

7. Chervyakova A.N., Gareev A.T., Vagizov A.M., Khisamiev T.R., Poisk perspektivnykh uchastkov dlya bureniya skvazhin i bokovykh stvolov s ispolʹzovaniem rezulʹtatov geologicheskogo modelirovaniya i geologo-promyslovogo analiza na primere TTNK Novo-Khazinskoy ploshchadi Arlanskogo mestorozhdeniya (Search for promising areas for drilling wells and sidetracks using the results of geological modeling and geological field analysis on the example of the terrigenous thickness of the Lower Carboniferous of Novo-Khazinskaya area of Arlan field), Collected papers “Aktual'nye nauchno-tekhnicheskie resheniya neftedobyvayushchego potentsiala PAO ANK “Bashneft'” (Current scientific and technical solutions to the oil production potential of Bashneft PJSC), 2016, V. 124, pp.

8. Zdolʹnik S.E., Nekipelov YU.V., Gaponov M.A., Introduction of innovative hydrofracturing technologies on carbonate reservoirs of Bashneft PJSOC (In Russ.), Neftyanoe Khozyaystvo = Oil Industry, 2016, no. 7, pp. 92–95.

In case of simulating carbonate reservoir with fractured cavernous structure, where fluids flow through a system of fractures, it can be possible to use the dual porosity systems, where matrix contains the main part of fluids in place. It is necessary to know that the properties of the reservoir for fractures and matrix are set separately. Experience shows that there are several features in the process of creating dual porosity/permeability models. Studying the properties of the matrix occurs according to the regulated methods and techniques. As for determining the characteristics of fractures like geometrical dimensions, permeability, productivity, these methods are mostly experimental or based on assumptions. Ultimately it can reduce the quality of simulation results.

In order to optimize the process of hydrodynamic simulation these types of reservoirs, for removing risks of geological structure and inconsistency of laboratory experiments with reservoir conditions (for fractured reservoir), the authors proposed a method for creating and history matching hydrodynamic models as a single porosity. The authors substantiated and applied a number of decisions, which aimed for changing principles of simulation of the reservoir. They were able to reproduce the complex work of matrix and fractures without using dual porosity model. And the main properties of the reservoir defined for a single rock. In the case of the single deposit, has been able to undertake a number of numerical experiments, which confirmed the selected decision.

The article discusses different solutions and tools that allow successful initialization and history matching of the hydrodynamic model of carbonate reservoir without using the dual systems of rock.

References

1. Lozin E.V., Geologiya i neftenosnost' Bashkortostana (Geology and oil content of Bashkortostan), Ufa: Publ. of BashNIPIneft', 2015, 704 p.

2. Burzunova Yu.P., Rock fractures near faults: specific features of structural-paragenetic analysis (In Russ.), Geodinamika i tektonofizika, 2017, V. 8, no. 3, pp. 673 – 693, doi:10.5800/GT-2017-8-3-0312

3. Golf-Racht T., Fundamentals of fractured reservoir engineering, Amsterdam, New York: Elsevier, 1982.

The article is devoted to the issue of increasing the efficiency of carbonate reservoirs development by improving stimulation technologies. Acid hydraulic fracturing is used in carbonate formations to make high conductive channels and join natural fractures network. Complex geological structure leads to the low efficiency of the use of acid compounds, which leads to a reduction of coherence of the system of fractures network and deterioration of production of wells. One of the ways to improve the efficiency of reservoir stimulation in these conditions is the use of technology of proppant-acid fracturing, which combines the advantages of both acid and proppant hydraulic fracturing. It allows to increase the coverage of carbonate deposits with increased heterogeneity by acid exposure, as well as to maintain opening of fractures during exploitation. The paper presents the results of the use of this type of hydraulic fracturing in the fields of the Republic of Bashkortostan: describes the basics of technology, the experience of its implementation and the process of evolution, the analysis of efficiency. On the basis of the analysis the authors determined the most effective conditions for the use of technology of proppant-acid fracturing for the fields of the region. The key conditions are to ensure the flow of fluid from the reservoir to the fixed fracture, as well as the presence of increased heterogeneity in the volume of the field. The first condition is met for medium and high permeability reservoirs developed with reservoir pressure maintenance system. The second is caused by the low coverage of acid composition of objects with the presence of interbedded insoluble rocks, natural channels of high conductivity. The revealed field of application allows to determine the optimal method of impact on the rock for each object, taking into account its geological and physical characteristics and the current state of development.

References

1. Latypov I.D., Efimov D.V., Murinov K.YU. et al., Razrabotka metodicheskogo obosnovaniya primenimosti tekhnologii GRP na karbonatnykh kollektorakh mestorozhdeniy, ehkspluatiruemykh OOO “Bashneftʹ-Polyus” (Development of a methodological substantiation of the applicability of hydraulic fracturing technology on carbonate reservoirs of fields operated by Bashneft-Polyus LLC), Collected papers “Aktual'nye nauchno-tekhnicheskie resheniya neftedobyvayushchego potentsiala PAO ANK “Bashneft'” (Current scientific and technical solutions to the oil production potential of Bashneft PJSC), 2016, V. 124, pp. 359–365.

2. Chekushin V.F., Kolesnikov A.A., Mukhametshin M.M., Litvinenko S.A., Wide implementation of fracturing on oil-fields of the Republic of Bashkortostan (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2012, no. 4, pp. 40–42.

Considering that light-capacity hoists have found wide application in Tatneft during well interventions and due to growing number of wells equipped with packer and anchor assemblies for artificial lift operations, conventional well intervention tools may fail to facilitate unsetting and retrieval of such equipment. This prompted engineers of TatNIPIneft Institute to develop DUG-40 wellhead hydraulic jack – a cost-effective solution to meet downhole challenges that does not require a workover rig.

Currently available are various wellhead jacks. These primarily have large cross slabs and stand on the ground. Such devices are extremely heavy and require mobile cranes for mounting, particularly in cases of high-set tubing or stuck hanger. Such jacks also require special preparatory arrangements at the wellhead area (construction of a work site, laying support plates). The main unique characteristics of DUG-40 include travel length of as high as 1 meter, upward extension of upside-down cylinder, landing into production casing coupling, and clamping capabilities due to application of two spiders. Jack lifting capacity is 500 kN. The hydraulic jack has simple design; low-set top clamp ensures easy operation of the device. Due to landing into wellhead connector, the jack allows to detach stuck tubing head adapter (tubing hanger) from wellhead adapter flange. Hydraulic jack design provides for hydraulically forced return of the cylinder to its original position by utilizing the annular space between piston rod and the cylinder. Pilot tests of the hydraulic jack have been conducted in wells operated by Tatneft Company. Various well intervention jobs have been conducted to gain the experience: unsetting of packers and anchors, stuck tools, tubing hanger.

The paper describes hydraulic jack design and operation as well as field test results in 14 wells, which confirmed its efficiency.

References

1. Domkrat gidravlicheskiy DG2-100 (Hydraulic jack DG2-100), URL: http://bno.su/domkrat-gidravlicheskiy-dg2-100

2. Ustanovka dlya izvlecheniya obsadnykh kolonn UIT-400 (Installation for the extraction of casing strings UIT-400), URL: http://oilprom-synergy.ru/neftepro­myslovoe-­oborudovanie/207-oborudovanie-dlya-remonta-skvazhin/ust...