Территория Нефтегаз № 8 2015

» Determination of direction of the maximum horizontal stress according to the vertical well directional survey data

When describing stress-strain behaviour of rocks, one of key tasks is to determine direction of the maximum horizontal stress. Today this task can be solved by performing additional downhole survey, which entails additional financial costs. We propose a method based on detailed study of vertical well directional survey. At drilling and completion stages the main tasks are well stability while drilling and integrity maintenance while its operation. The first task was a traditional task of geomechanics; the second one recently was the focus of attention, especially at mature fields. Stress change and overload caused by compaction of the reservoir bed during operation require specific technical conditions, e.g. forecasting of changes of the fracture gradient and its impact on the well bore. This often leads to high equipment costs and costs associated with increase of drilling process duration. A key component of geomechanical model is knowledge of the current stress-strain behaviour of rocks. Most collapses of well walls are caused by stresses in the circumference of the well bore that exceed the maximum strength of rocks. These are so-called shear stresses that are a deterrent preventing cavings and at the same time (in case of excessive imbalance along the well radius) lead to its walls destruction. This effect is caused by change of the initial rock stress field while drilling and due to well pressure.

Keywords: stress-strain behaviour of rocks, direction of horizontal stress, well directional survey, stress.

Authors:

A.A. Podyachev, Samara State Technical University (Samara, Russia), assistant of the Oil and Gas Well Drilling Department, e-mail: smtu@bizfix.ru;
I.V. Dorovskikh, Samara State Technical University (Samara, Russia), Candidate of Science (Engineering), e-mail: dorovskikhiv@gmail.com;
V.V. Zhivayeva, Samara State Technical University (Samara, Russia), Candidate of Science (Engineering), Head of the Oil and Gas Well Drilling Department, e-mail: bngssamgtu@mail.ru

References:

1. Guizhong C., Chenevert M.E., Sharma M.M., Yu M. A study of wellbore stability in shales including poroelastic, chemical, and thermal effects. Journal of Petroleum Science and Enginnering, 2003, No. 38. P. 27–32.
2. Bradley W.B. Mathematical concept – stress cloud can predict borehole failure. Oil Gas J., 1979a.
3. Bradley W.B. Failure of indicate boreholes. J. Energy Resour. Technol., Trans. ASME 101. 1979b.

For citation:
Podyachev A.A., Dorovskikh I.V., Zhivayeva V.V. Determination of direction of the maximum horizontal stress according to the vertical well directional survey data (In Russ.). Territorija «NEFTEGAZ» = Oil and Gas Territory, 2015, No. 8. P. 16–18.

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» Predicting of reservoir pressure in the clay-shale reservoirs with the use of the region С of the Ordos field

The dominant component of absorptive gas in the total amount of oil shale deposits has been shown. The reservoir pressure directly impacts the shale gas adsorption as well as hydraulic fracturing design. A correct forecast of the reservoir pressure plays an integral role both in shale deposit reserves calculation and mining method design. Abnormal low pressure was predicted in the region C of the Ordos field in reservoirs С7, С9. According to the analysis of drilling data (drilling speed, dc-index) the article shows that the reservoirs under investigation carry abnormally high pressure and this information gives a chance to correct the previous forecast error. The reservoir pressure directly affects the adsorption of shale gas: the more the reservoir pressure is the more adsorptive gas is there. Laboratory studies through building multiple models confirmed that the presence of adsorptive gas is in functional relation with temperature and pressure. That is why the right forecast in the investigation of interstitial shale gas pressure is of vital importance. To predict the geostatic pressure by three methods, the density of the surface has been synthesized. The Eaton method in the Gulf of Mexico has been shown as the effective one and the most widespread worldwide to predict interstitial pressure. The Eaton method calculates the abnormally high pressure that changes in the range of 20–28 MPa. We came to conclusion that the result of sample pulse testing shows the rock features in case of normal thickening. Pulse method is effective for normal line thickening trimming.

Keywords: share gas, abnormally high formation pressure, geostatic pressure, pulse method, Eaton method, synthesizing density.

Authors:

M.A. Lobusev, RSU of oil and gas named after I.M. Gubkin (Moscow, Russia), PhD (tech.), senior lecturer of the Dept. of Production Geology;
Song Zezhang, RSU of oil and gas named after I.M. Gubkin (Moscow, Russia), graduate of Production Geology;
Jiang Zhenxue, Institute of unconventional gas China University of Petroleum (Beijing, China), Professor, Dean

References:

1. Kanalin V.G., Vagin S.B., Tokarev M.A. Neftepromyslovaja geologija i gidrogeologija [Oil-field geology and hydro geology]. Мoscow, Nedra Publ., 1997.
2. Lobusev A.V., Strakhov P.N., Lobusev M.A. Novyj podhod k ocenke i prognozu produktivnosti neftegazonasyshhennyh porod [A new approach to the evaluation and forecast of hydrocarbon filled rocks productivity]. Akademicheskij zhurnal Zapadnoj Sibiri = West Siberia Academical Journal, 2014, No. 2 (51), Vol. 10. P. 45–46.
3. Chzhan Tszinchuan, Syuy Bo, Ne Khaykuan. Potencial razvedki slancevogo gaza v Kitae [Potential of shale gas exploration in China]. // Gazovaja promyshlennost' = Gas Industry, 2008, No. 6 (28). P. 136–140.
4. Tan In, Chzhan Tszinchuan, Lyu Chzhutszyan et al. Metodom desorbcii izmerit' soderzhanie slancevogo gaza i uluchshenie metoda [Desorption method to measure the content of the shale gas and improving of method]. Gazovaja promyshlennost' = Gas Industry, 2011, No. 10 (31). P. 108–111.
5. Syun Vey, Go Vey, Lyu Khunlin et al. Harakteristiki slancevogo kollektora i harakteristiki izotermicheskoj adsorbcii slanca [Characteristics of shale pool and characteristics of isothermal shale adsorption]. Gazovaja promyshlennost' = Gas Industry, 2012, No. 01 (32). P. 113–116.
6. Mario A.G., Neil R.B., Brent A.C. Calibration and ranking of pore-pressure prediction models. The Leading Edge, 2006, 25(12): 1516–1523.
7. Eaton B.A. The Effect of Overburden Stress on Geopressure Prediction from Well Logs. Journal of Petroleum Technology, 1972.
8. Eaton B.A. The Equation for Geopressure Prediction from Well Logs. SPE5544, 1975.
9. Eaton B.A., Eaton T.L. Fracture gradient prediction for the new generation. World Oil, 1997: 93–100.
10. Watching Rocks Change – Mechanical Earth Modeling. Oilfield review. 2003.

For citation:
Lobusev M.A., Song Zezhang, Jiang Zhenxue. Predicting of reservoir pressure in the clay-shale reservoirs with the use of the region С of the Ordos field (In Russ.). Territorija «NEFTEGAZ» = Oil and Gas Territory, 2015, No. 8. P. 20–28.

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» Stress-strain analysis of APRS-40 unit tower with the use of computer simulation

The article presents the results of computer simulation of stress-strain state (SSS) of steel structure of APRS-40 unit tower for underground repair and overhaul of wells. It briefly describes the method of creating tower solid model. The article includes comparative results of stress-strain state changing under various support loads and angles of inclination, as well as in case of incomplete attachment of tower extending section to supports. Creation of solid model and examination of its SSS are performed by KOMPAS-3D computer-aided design system and APM FEM specialized calculation module that implements the finite element method. When modeling SSS, three problems of practical interest for operation of the unit structure are solved: 1) SSS modeling of the tower structure with increase of static loads from 100 to 500 kN; 2) SSS modeling of the tower structure with increase of angle of inclination to the well axis from 0° to 6° and at angles of 9° and 12°; 3) SSS modeling of the tower structure with no attachment of extending section to one or more supports. Following survey results, data was obtained allowing to assess the SSS level at various angles of inclination of the tower to the well axis at various stages of loading during operation. It was found that the structure can operate in the most secure way only without attachment to the rear right support due to the fact that the assurance factor decreases in inverse proportion to operating load increase. The developed model can be used in practice for preliminary assessment of SSS of APRS-40 unit tower structures. The model can be quickly modified and adjusted for various tasks, including modeling of various defects in the tower structure.

Keywords: computer simulation, stress-strain state, the metal structure of the match, the factor of safety, dependence.

Authors:

I.Yu. Bykov, Ukhta State Technical University (Ukhta, Russia), doctor of science (Engineering), professor;
D.A. Boreiko, Ukhta State Technical University (Ukhta, Russia), post-graduate student, e-mail: diacont_dboreyko@mail.ru

References:

1. Seliverstov G.V., Butyrskiy S.N., Voblikova Yu.O. Analiz naprjazhenno-deformirovannogo sostojanija jelementov metallokonstrukcij gruzopod’emnyh mashin [Analysis of stress-strain state of steel structure components of hoisting machinery]. Bulletin of Tula State University. Technical Sciences, 2009, No. 2-1. P. 124–126.
2. KOMPAS-3D V15. User's manual, ASKON. 2014. 2488 pp

For citation:
Bykov I.Yu., Boreiko D.A. Stress-strain analysis of APRS-40 unit tower with the use of computer simulation (In Russ.). Territorija «NEFTEGAZ» = Oil and Gas Territory, 2015, No. 8. P. 98–104.

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» Prospects of application of formation fluid magnetic treatment to control the electric submersible pumps efficiency in abnormal operating conditions

The current state of the oil and gas industry is conditional upon the trend of deterioration in the quality of the resource base, increase in the proportion of tight reserves in the structure of the oil companies’ assets, and as a consequence of complications of operation conditions. At the moment, due to the situation of price conjuncture in the global oil market, the issue of reducing the operating costs on oil production is becoming acute. These assumptions and current conditions dictate oil and gas companies the conditions for the formation of the main development strategies. Accordingly, the basic strategy is to reduce the unit costs on the production of 1 ton of oil by 5 to 10% in the next few years. World oil and gas practice shows that approximately 20% of the wells operated by means of mechanized mining method are equipped with electric submersible pump (ESP) units — this figure, in terms of quantity, is about 180,000 wells. The main negative impact on the technical and economic indicators of the work of well equipped with ESP is made by the geological group of complications, such as: free gas, unfree water, salt and paraffin deposits, sand ingress – mechanical impurities. The nature and characteristics of these complications are formed due to the formation of oil and gas deposits, and are manifested during the interaction of the extracted fluid as a source of complications with the used equipment. The objective of any oil and gas company is to increase the meantime between failures for ESP submersible equipment, and the solution to this problem is an integral part of the strategy to reduce the unit costs and improve the efficiency of artificial oil lift. The article presents the prospects of the technology of formation fluid magnetic treatment in order to increase performance indicators of a well equipped with an ESP unit. This method is promising in regard to easy technical solutions, high performance, and seriousness of the effect caused, as well as a complex treatment of problems.

Keywords: electric submersible pump (ESP) unit, complex operating conditions, well production performance indicators, methods of performance management, magnetic field impact on oil, prospect of application.

Authors:

A.V. Ushakov, National Research Tomsk Polytechnic University (Tomsk, Russia), doctoral student, e-mail: av_ushakov@rosneft.ru

References:

1. Smirnov N.I. Issledovanie vlijanija iznosa na resurs UJeCN [Study of the wear-out effect on an ESP unit lifetime]. Sbornik trudov mezhdunarodnoj nauchno-tehnicheskoj konferencii «Aktual'nye problemy tribologii» [Proceedings of the international scientific and technical conference «Topical issues of the tribology»], 2007, Vol. 1. P. 410–416.
2. Shubin S.S. Metodicheskoe i jeksperimental'noe obespechenie opredelenija tehnicheskogo sostojanija ustanovok jelektrocentrobezhnyh nasosov v processe jekspluatacii. Dis. … kand. tehn. nauk [Methodical and experimental ware for determination of electric submersible pump unit technical state during the operational process. Candidate of Science (Engineering) dis.]. Ufa State Petroleum Technological University. Ufa, 2014.
3. Gushchin N.S., Kovalevich Ye.V., Petrov L.A., Pestov Ye.S. Novyj metod izgotovlenija rabochih organov pogruzhnyh centrobezhnyh nasosov iz austenitnogo chuguna s sharovidnym grafitom [New method of production of operative parts of austenitic cast iron submersible rotary pumps with spherical graphite]. Vestnik Magnitogorskogo gosudarstvennogo tehnicheskogo universiteta im. G.I. Nosova = Vestnik of Nosov Magnitogorsk State Technical University, 2008, No. 4. P. 44–48.
4. Gluskin Ya.A., Palchikov А.I. Stupen' pogruzhnogo mnogostupenchatogo centrobezhnogo nasosa [Phase of submersible multi-stage rotary pump]. RU patent (11) 2220327 (13) C2 Available at: http://www.findpatent.ru/patent/244/2446316.html (accessed 08.05.2015).
5. Kruglov S.V. Rabota detalej UJeCN s polimernym zashhitnym pokrytiem [Component operation of the ESP unit with polymer protective coating]. Inzhenernaja praktika = Engineering practice, 2010, No. 6. P. 105–109.
6. Prozhega М.V. Razrabotka metodov povyshenija iznosostojkosti radial'nyh par trenija skol'zhenija jelektricheskih centrobezhnyh nasosov. Dis. kand. tehn. nauk [Development of methods for improving the wear hardness of radial friction pairs of electric submersible pumps. Candidate of Science (Engineering) Diss.]. Blagonravov Machine Science Institute of the Russian Academy of Sciences. Moscow, 2009.
7. Bremner Ch. et al. Razvivajushhiesja tehnologii: pogruzhnye jelektricheskie pogruzhnye nasosy [Developing technology: electrical submersible pump units]. Neftegazovoe obozrenie = Oilfield Review, 2006/2007, Vol. 18, No 4. P 36–51.
8. Vedernikov V.А. Modeli i metody upravlenija rezhimami raboty i jelektropotrebleniem pogruzhnyh centrobezhnyh ustanovok. Dis. dokt. tehn. nauk [Models and management technology of production conditions and power consumption of submersible centrifugal pump. Doctor of Science (Engineering) Diss.]. Tyumen State Oil and Gas University. Tyumen, 2006.
9. Vedernikov V.А., Gapanovich V.S., Kozlov V.V. Osobennosti primenenija pogruzhnyh jelektrocentrobezhnyh nasosov na neftjanyh mestorozhdenijah Srednego Priob'ja [Features of the electrical submersible pumps usage on oilfields of the Middle Ob]. Vestnik kibernetiki = Cybernetics Herald, 2008, No. 7. P. 27–32
10. Gumerov K.O. Povyshenie jeffektivnosti jekspluatacii skvazhin jelektrocentrobezhnymi nasosami v uslovijah vjazkih vodoneftjanyh jemul'sij. Dis. kand. tehn. nauk [Improving of the well operation efficiency with the use of electric submersible pumps in viscous oil-water emulsions environment. Candidate of Science (Engineering) diss.]. National Mineral Resources University (Mining Institute). St. Petersburg, 2015.
11. Lekomtsev А.V. Metodika podbora jelektrocentrobezhnyh nasosov v skvazhiny s vysokim gazovym faktorom na mestorozhdenijah Verhnego Prikam'ja [Method of electric submersible pumps selection in wells with high oil-gas ratio on the Upper Kama region deposits]. Razrabotka poleznyh iskopaemyh i geodezija: materialy nauch.-praktich. konf. = Resource development and geodesy: materials of the research and practice conference, March 2012. Available at: http://www.sworld.com.ua/index.php/ru/technical-sciences-112/mining-and-geodesy-112/12631-112-787 (accessed 08.05.2015).
12. Topolnikov А.S., Litvinenko К.V., Ramazanov R.R. Kompleksnyj podhod k proektirovaniju shemy mehanizirovannoj dobychi nefti v uslovijah vynosa mehprimesej [A complex approach to the design of lifting scheme with the solids wash-over]. Inzhenernaja praktika = Engineering practice, 2010, No. 2. P. 84–90.
13. Martyushev D. Zashhita ot mehanicheskih primesej [Protection against contamination]. Arsenal neftedobychi = Oil extraction toolkit, 2008, No. 1 (04).
14. Antipin Yu.V., Gilmutdinov B.R., Mustafin R.S., Ayupov A.R. Ispol'zovanie ingibirujushhih kompozicij v sostave azotsoderzhashhej peny dlja bor'by s korroziej i soleotlozheniem v skvazhinah [Use of inhibiting compositions as a part of nitrogen-containing foam to prevent corrosion and scaling in wells]. Neftegazovoe delo = Oil and Gas Business, 2009, Issue. 1. P. 149–154.
15. Shablya V.V. Opyt raboty TPP «Kogalymneftegaz»s soleobrazujushhim fondom skvazhin [Operating experience of territorial production unit Kogalymneftegaz with salt-forming foundation of wells]. Inzhenernaja praktika = Engineering practice, 2009, Pilot issue. P. 22–25.
16. Zhuyko P.V. Razrabotka principov upravlenija reologicheskimi svojstvami anomal'nyh neftej. Dis. dokt. tehn. nauk [Development of management principles of abnormal oil flow properties. Doctor of Science (Engineering) Diss.]. Ukhta State Technical University, 2003.
17. Spiridonov R.V., Demakhin S.A., Kivokurtsev A.Yu. Magnitnaja obrabotka zhidkostej v neftedobyche [Magnetic treatment of fluids during oil production]. Saratov: GosUNTs College Publishing House, 2003. 136 pp.
18. Loskutova Yu.V., Yudina N.V. Vlijanie magnitnogo polja na strukturno-reologicheskie svojstva neftej [The influence of magnetic field on the structural and rheological properties of oils]. Izvestija Tomskogo politehnicheskogo universiteta = Bulletin of the Tomsk Polytechnic University, 2006, Vol. 309, No. 4. P. 104–109.
19. Dokichev V.A., Svirskiy S.E., Singizova V.Kh., Kresteleva I.V., Telin A.G. Vlijanie magnitnogo polja na dejemul'saciju vodoneftjanoj jemul'sii plasta A4 Kiengopskogo mestorozhdenija [The influence of magnetic field on de-emulsification of oil-water emulsion of the А4 reservoir of the Kiengopskoe field]. Available at: http://pismoref.ru/3830064012.html (accessed 08.05.2015).

For citation:
Ushakov A.V. Prospects of application of formation fluid magnetic treatment to control the electric submersible pumps efficiency in abnormal operating conditions (In Russ.). Territorija «NEFTEGAZ» = Oil and Gas Territory, 2015, No. 8. P. 44–50.

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» Information system for analysis and monitoring of artificial lift well operation for optimization business processes of oil production

The article presents the development of an information system (IS) for the optimization of business processes associated with artificial lift. Preconditions of creation IS associated with great complexity preparation and absence of a single source
of input data for analysis and settlement, the lack of common methods and algorithms, low-urgency alerts specialists to critical deviations, the need for centralized performance assessment of personnel, equipment and technologies fight against complications, as well as the presence of multiple information systems which are not integrated with each other. To solve these problems of the analysis and monitoring of artificial lift wells there are several modules as parts of IS «ERA.Mehfond». Storing all data in a single repository, the introduction of common classifications, the introduction of analytical tools, the lack of duplication of data, real-time monitoring and alerting deviations, automation optimization measures will increase oil production, increase operating time of the submersible pump equipment failures, and significantly reduce labor costs. Currently, through the development of an information system analysis and monitoring of a transition to a proactive approach to decision-making processes of artificial lift. In contrast to the previously used reactive approach will enable it to anticipate developments and implement preventive interventions in the case of emergency situations. This approach will give a significant effect due to the reduction of losses, and in the future can practically eliminate unproductive losses.

Keywords: artificial lift, information system, submersible pumping equipment.

Authors:

A.N. Drozdov, Gubkin Russian State University of Oil and Gas (Moscow, Russia), Doctor of Science (Engineering), Professor, e-mail: Drozdov_AN@mail.ru;
R.D. Khamidullin, ITSK LLC (Moscow, Russia), Director General;
D.A. Shestakov, ITSK LLC (St. Petersburg, Russia), Deputy Director of Development Centre on Exploration and Production Block Direction;
N.P. Sarapulov, Gazpromneft Research and Development Center LLC (St. Petersburg, Russia), expert on artificial lift technology;
R.A. Khabibullin, Gazpromneft Research and Development Center LLC (St. Petersburg, Russia), Candidate of Science (Physics and Mathematics), discipline head

References:

1. Doctor S.A., Korolev D.M., Sarapulov N.P. et al. Podhod k upravleniju mehanizirovannoj dobychej v ramkah razvitija sistemy «Jelektronnaja Razrabotka Aktivov» [Organising artificial lifting management: example of Electronic Fields Development project]. Neftjanoe hozjajstvo = Oil Industry, 2013, No. 12.

For citation:
Drozdov A.N., Khamidullin R.D., Shestakov D.A., Sarapulov N.P., Khabibullin R.A. Information system for analysis and monitoring of artificial lift well operation for optimization business processes of oil production (In russ.). Territorija «NEFTEGAZ» = Oil and Gas Territory, 2015, No. 8. P. 34–43.

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» Pipeline service life assessment procedure

The procedure of the gas pipelines service life assessment during the operational phase was developed, thus the following mechanisms of degradation and damaging factors were considered: corrosion, stress corrosion cracking, fatigue and violation of the design gas pipeline position. The analysis results of degradation mechanisms and damaging factors showed that the main factor which is determinative for the gas pipelines service life assessment is fatigue, as damage from fatigue in contrast to damage from corrosion defects and stress corrosion, as well as increased stress levels, is impossible to eliminate during operation. To assess the fatigue life, a model based on the design fatigue curve, coefficients of which are determined by cyclic testing of samples up to destruction, and decrease of fatigue life in the presence of multiple damages (defects) in the operated pipeline is corrected by the adjustment factor. For harmful factors associated with corrosion and corrosion stress cracking, a model of the gas pipeline safe operation assessment by corrosion and corrosion stress conditions for time of the technical diagnosis appointment to determine its technical condition and action plan for the diagnostic and repair works drawing up was proposed. Model of the gas pipeline safe operation assessment by corrosion conditions takes into account the corrosion state of the analogue gas pipeline and the protective coating service life. Analogue gas pipeline corrosion condition is assessed by exponential ranks distribution law of the corrosion defects danger, the parameters of which are determined by statistical treatment of in-line technical diagnostics results. As an example, the service life of the main gas pipeline «Urengoy – Novopskov» section was determined its operating time is 31 years. The design service life of the gas pipeline is 90 years at the outside diameter of 1,420 mm, wall thickness of 17.5 mm and design pressure of 7.4 MPa. For this initial data the gas pipeline service life calculated during the operational phase, is 74 years.

Keywords: gas pipeline, service life, corrosion state, in-line technical diagnostics.

Authors:

I.I. Veliyulin, Orgremdigaz Center Orgenergogaz JSC (Moscow, Russia), Doctor of Science (Engineering), Director;
V.I. Gorodnichenko, Orgremdigaz Center Orgenergogaz JSC (Moscow, Russia), Candidate of Science (Engineering), Chief Technologist, e-mail: v.gorodnichenko@oeg.gazprom.ru;
M.A. Shirokov, Orgremdigaz Center Orgenergogaz JSC (Moscow, Russia),
Department Head

References:

1. Procedure for safe operation extension of technical devices, equipment and structures at hazardous production facilities (In Russ.). Approved by Order of the Ministry of Natural Resources of the Russian Federation No. 195 dated 30.06.2009.
2. Federal Law No. 116-FZ «On industrial safety of hazardous production facilities» (In Russ.), dated 21.07.1997.
3. R Gazprom 2-2.1-369-2009 «Guidelines for the linear part of main gas pipelines service life assessment during the design phase» (In Russ.).
4. R Gazprom 2-2.3-609-2011 «Definition of decommissioning for complex repair criteria and terms of compressor station process pipelines safe operation» (In Russ.).
5. STO Gazprom 2-2.3-292-2009 «Rules for determination of technical condition of main gas pipelines subject to inline inspection results» (In Russ.).
6. STO Gazprom 2-2.3-095-2007 «Guidelines for the diagnostic examination of the main gas pipelines linear part» (In Russ.).
7. STO Gazprom 2-3.5-454-2010 «Rules of the main gas pipelines operation» (In Russ.).
8. STO Gazprom 2-2.3-173-2007 «Instruction for complex examination and diagnostics of main gas pipelines exposed to corrosion cracking under tension» (In Russ.).
9. Instructions for the pipes and fittings defects evaluation during the main gas pipelines repair and diagnostics (In Russ.). Approved by Deputy Chairman of the Board of Gazprom JSC 05.09.2013.
10. Vorobyev A.Z., Olkin B.I., Stebenev V.N., Rodchenko T.S. Soprotivlenie ustalosti jelementov konstrukcij [Fatigue resistance of constructional elements]. Moscow: Mechanical Engineering, 1990.
11. Salyukov V.V., Mitrokhin M.Yu., Molokanov A.V., Gorodnichenko V.I. Metodologija ocenki pokazatelja tehnicheskogo sostojanija linejnogo uchastka MG po rezul'tatam VTD [Methodology of the main gas pipeline linear part technical state assessment upon in-line inspection results]. Gazovaja promyshlennost' = Gas industry, 2009, No. 4. P. 47–50.
12. STO Gazprom 2-3.5-252-2008 «Procedure of safe operation period extension of the Gazprom JSC main gas pipelines» (In Russ.).

For citation:
Veliyulin I.I., Gorodnichenko V.I., Shirokov M.A. Pipeline service life assessment procedure (In Russ.). Territorija «NEFTEGAZ» = Oil and Gas Territory, 2015, No. 8. P. 106–111.

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» Modeling of pump station stoppage mode

The article discusses modeling of oil pump stations (OPS) stoppage mode happening during oil transporting pipeline operation. In cases of stopping, the transfer of oil does not stop immediately, it ceases gradually within a specified period of time called pump stoppage duration. In the process of station stoppage pressure in the suction line increases, pressure in the discharge line decreases, as the differential pressure of the pump and flow rate increase too. Caused changes propagate as waves move upstream and downstream of the pipeline, causing significant fluctuations in pressure. Since these fluctuations represent a significant threat to the integrity of the oil pipeline, the period of stoppage mode, which can range from 15 to 45 s, cannot be neglected. In some cases, different protection systems are installed upstream of the PS, including the pipeline surge relief systems (PSRS) reacting mainly on the rate of pressure increase [1]. If this speed exceeds a predetermined value, it forces the valve to open and allows oil to be discharged from the pipeline into a drain tank. That is why pressure increase rate in front of the pump station and the stoppage mode duration are considered to be in area of interest. Despite the fact that stoppage mode has been studied by many researchers at different times [2, 3], a definitive answer to the question of the duration of the process and the parameters that affect it, as well as the method of calculation of these parameters remained open. The article sets the task to fill this gap.

Keywords: oil pipeline, pump station, pump stoppage, pressure, head, flow rate, angular velocity, moment of inertia, modeling, stoppage duration, numerical calculation.

Authors:

A.S. Didkovskaya, Gubkin Russian State Oil and Gas University (Moscow, Russia), PhD, associate professor of the Design and operation of oil and gas pipelines Department, e-mail: didal@gubkin.ru;
M.V. Lurie, Gubkin Russian State Oil and Gas University (Moscow, Russia), PhD, professor of the Design and operation of oil and gas pipelines Department, e-mail: lurie254@gubkin.ru

References:

1. Fedoseyev M.N., Lurie M.V., Arbuzov N.S. Matematicheskoe modelirovanie raboty sistem sglazhivanija voln davlenija [Mathematical modelling of pipeline surge relief systems operation]. Territorija «NEFTEGAZ» = Oil and Gas Territory, 2015, No. 6. P. 28–34.
2. Polyanskaya L.V. Issledovanie nestacionarnyh processov pri izmenenii rezhima raboty nefteprovodov s centrobezhnymi nasosami. Diss. kand. tehn. nauk. [Non-steady processes study at oil pipelines with centrifugal pumps operation mode changing. Thesis of Candidate of Science (Engineering)]. Gubkin Moscow Institute of the Petrochemical and Gas Industry, 1965. 141 pp.
3. Vyazunov Ye.V. Priblizhennyj metod postroenija zavisimosti davlenija vsasyvanija ot vremeni posle otkljuchenija nasosnoj stancii [Approximate method of plotting suction pressure and time after the pump station shut-off dependence]. Transport i hranenie nefti i nefteproduktov = Oil and oil products transportation and storage, 1966, No. 2. P. 14–16.
4. Didkovskaya A.S., Lurie M.V. Modelirovanie processa puska nasosov promezhutochnoj nefteperekachivajushhej stancii [Modelling of the intermediate oil booster station pumps start process]. Territorija «NEFTEGAZ» = Oil and Gas Territory, 2015, No. 3. P. 118–122.
5. Lurie M.V. Matematicheskoe modelirovanie processov truboprovodnogo transporta nefti, nefteproduktov i gaza [Mathematic modeling of processes of oil, oil products and gas pipeline transportation]. Moscow: Publishing Center of Gubkin Russian State University of Oil and Gas, 2012. 456 pp.

For citation:
Didkovskaya A.S., Lurie M.V. Modeling of pump station stoppage mode (In Russ.). Territorija «NEFTEGAZ» = Oil and Gas Territory, 2015, No. 8. P. 90–95.

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» Main pipelines, repaired with split couplings, performance analysis

This article is dedicated to the low service life of welded split couplings. Current trend in ensuring the pipelines safety – works on the technical state – opens the way for the rational resources use, however it requires the development of two
trends: on the one hand, diagnostic means, including equipment for the detection of defects and methods for assessing their risk, and on the other hand – the means for prompt elimination of dangerous damages with minimal delay in fuel
pumping. Various organizations have currently developed wide range of repair structures, some of them are included in the regulation documents for gas and oil industries. Many of them, despite the complexity and high cost, do not ensure the pipeline repaired section full recovery. The practical application of such structures can lead to the big accidents quantity before assigned resource expiration. This article analyzes the main problems during various repair couplings installation and subsequent pipelines repair. Couplings operation conditions computer modeling is used for analysis. Close attention is paid to the cyclic strength of the circular welded seams, joining the coupling with pipe. The results of field tests of the pipe sections repaired with the most complex coupling type, split tee, are analysed. The causes of conflicts in regulations, leading to wrong choice of the repair structure wall thickness are identified. Tee design, providing the full refurbishment of operation life cycle at the level of undamaged pipe, is developed on the results of researches and tests. Results are included in industry regulatory document.

Keywords: split coupling, service life, pipeline repair, stress condition, field tests.

Authors:

A.S. Kurkin, Bauman Moscow State Technical University (MSTU) (Moscow, Russia), Doctor of Science (Engineering), professor, e-mail: ackurkin@mail.ru;
E.L. Makarov, Bauman MSTU (Moscow, Russia), Doctor of Science (Engineering), professor;
S.A. Korolev, Bauman MSTU (Moscow, Russia), Candidate of Science (Engineering), associate professor;
P.A. Ponomarev, Bauman MSTU (Moscow, Russia), postgraduate;
M.A. Ponomarev, Bauman MSTU (Moscow, Russia), student;
V.V. Bondarenko, KONAR CJSC (Chelyabinsk, Russia), Candidate of Science (Engineering), Director General

References:

1. Kurkin A.S., Korolev S.A., Ponomarev P.A. Analiz prichin ogranichennogo resursa konstrukcij dlja remonta nefteprovoda [Analysis of the reasons for limited service life of structures for pipeline repair]. Svarka i diagnostika = Welding and diagnostics, 2014, No. 5. P. 58–61.
2. Kurkin A.S., Makarov E.L. Programmnyj kompleks «SVARKA» – instrument dlja reshenija prakticheskih zadach svarochnogo proizvodstva [WELDING program complex is the instrument for solving the welding production practical tasks]. Svarka i diagnostika = Welding and diagnostics, 2010, No. 1. P. 16–24.
3. RD-75.180.00-KTN-193-08 (revised in 2005, revised in 2009) Tehnologija ustanovki remontnyh konstrukcij na truboprovody diametrom 1067 i 1220 mm s davleniem 10 MPa [Technology for installation of repair structures on pipelines with diameter of 1,067 and 1,220 mm with pressure of 10 MPa]. Commissioned on 14.11.2008. Transneft JSC, 2008. 70 pp. (In Russ.)
4. Zainullin R.S., Vorobyev V.A., Aleksandrov A.A. Povyshenie bezopasnosti nefteproduktoprovodov remontnymi muftami [Improving the safety of oil pipelines with repair couplings]. Edit. by prof. R.S. Zainullin. Ufa: Printing and Publication Department, Republican Academic Methodical Centre, RB Ministry of Education, 2005. 119 pp.

For citation:
Kurkin A.S., Makarov E.L., Korolev S.A., Ponomarev P.A., Ponomarev M.A., Bondarenko V.V. Main pipelines, repaired with split couplings, performance analysis (In Russ.). Territorija «NEFTEGAZ» = Oil and Gas Territory, 2015, No. 8. P. 84–88.

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» Study of the effect of heat treatment pipeline fittings made of high strength steels on the change of strength characteristics

Due to transition to the natural gas transportation pressurized to 9.8–11.8 MPa, application of pipes and fittings made from high-strength steel with strength category K60 became promising. This provides for high requirements for their technical condition and performance characteristics. The process of manufacturing pipeline fittings is associated with repeated metal heating that negatively affects its strength characteristics. At the same time, metal in finished products has to comply with category K60 of strength steel. This requirement can be met only in the result of final heat treatment. This article is dedicated to assessment of the possibility to provide required strength properties of pipeline fittings based on the study of specific kinetic features of the transformation of 10G2FBY austenite high-strength steel during heat treatment. The study was carried out using specialized hardware installed in the laboratories of the Department «Welding and Monitoring of Oil and Gas Facilities» at Gubkin Russian State University of Oil and Gas. The study comprised the following phases: The study of the grain growth kinetics with increasing of the heat treatment up to 1,100 °C; Plotting of anisothermal diagrams of austenite decomposition in weld joints during thermal treatment; Assessing the feasibility of the recommended heat treatment modes. According to the study result the influence of heat treatment parameters was established within the mode «quenching with high-temperature tempering» on the structure, hardness and toughness of the base metal and welded joints in stamped elbows. By experimental method, conditions were defined for reproduction of required cooling rates that ensure strength characteristics at the rated level.

Keywords: kinetics of austenite decomposition, pipe fittings, heat treatment.

Authors:

L.A. Efimenko, Gubkin Russian State University of Oil and Gas (Moscow, Russia), Dr. Sci., Professor, e-mail: lefimen@yandex.ru;
A.O. Merkulova, Gubkin Russian State University of Oil and Gas (Moscow, Russia), Assistant, e mail: а rina_merkulova@list.ru;
O.S. Puyko, Trubodetal OJSC (Chelyabinsk, Russia), leading engineer of the lab metallography of the Engineering centre, e-mail: Shchekalova.A@trubodetal.ru;
A.A. Schekalova, Trubodetal OJSC (Chelyabinsk, Russia), process engineer 2nd categories, e-mail: Shchekalova.A@trubodetal.ru

References:

1. Morozov U.D., Matrosov M.U. , Nastich S.U. Vysokoprochnye trubnye stali novogo pokolenija s ferrito-bejnitnoj strukturoj [High steel pipe with a new generation ferritic-bainitic]. Metallurg = Steelworker, 2008, No. 8. P. 39–42.
2. Botvinnikov A.U., Neufeld O.I., Efimenko L.A. Vlijanie termicheskoj obrabotki na strukturu i svojstva svarnyh soedinenij shtamposvarnyh detalej iz stali 10G2FBJu [Effect of heat treatment on the structure and properties of welded joints of stamped parts made of steel 10G2FBYU]. // Tehnologija mashinostroenija = Manufacturing Engineering, 2009, No. 4. P. 10–12.
3. Efimenko L.A., Prigaev A.K., Elagina O.U. Metallovedenie i termicheskaja obrabotka svarnyh soedinenij [Metallurgy and heat treatment of welded joints]. Moscow, Logos Publ., 2007. 456 pp., ill.
4. Efimenko L.A., Neufeld O.I. Issledovanie osobennostej kinetiki raspada austenita pri svarke stali 10G2FBJu [Investigation of the features of the kinetics of decomposition of austenite during of welding steel 10G2FBYU]. Himicheskoe i neftegazovoe mashinostroenie = Chemical and Petroleum Engineering, 2008, No. 5. P. 47–48.
5. STO Gazprom 2-4.1-273-2008 Technical requirements for connecting parts for the facilities of Gazprom (In Russ.).
6. STO Gazprom 2-4.1-713-2013 Specifications for pipes and fittings (In Russ.).

For citation:
Efimenko L.A., Merkulova A.O., Puyko O.S., Schekalova A.A. Study of the effect of heat treatment pipeline fittings made of high strength steels on the change of strength characteristics (In Russ.). Territorija «NEFTEGAZ» = Oil and Gas Territory, 2015, No. 8. P. 76–82.

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» Mechanical test method features for measurement of fracture toughness in steel tube weld joints, used in Gazprom Co objects

The article deals with contemporary standardized test procedures of cracking base metal and circumferential weld of pipe joints used in main pipeline systems constructing. The results of mechanical crack tests presented in the article: с (CTOD) – critical crack tip opening, obtained in strict accordance with the requirements and recommendations of a number of international standards [1–5] worldwide used in practice. Several differences in regulations and ambiguity were found out while analyzing the mechanical tests results and regulatory documents used by authors. Main of these differences and ambiguity are the next: requirements to notch location in a specimen; requirements to location of crack tip fatigue increment and total crack length; requirements to crack tip straightness; requirements to stress intensity factor ramp in fatigue loading of notch length increment process; requirements to locations of fracture toughness test specimens in certain zones of pipe butt weld perimeter and others. Whereas a fulfillment of these requirements has a large influence on reliability of mechanical crack tests. As a result of experimental work and test data analysis the authors have formulated suggestions for removing of represented above differences and ambiguity in standards and improving the regulations used by Gazprom Co in main pipeline systems constructing. Consequently the reliability of mechanical tests will increase.

Keywords: frature toughness test, critical CTOD method determination, weld pipeline, fatigue crack, validity requirements for fracture toughness characteristics.

Authors:

M.I. Antonov, Peter the Great St. Petersburg Polytechnic University (St. Petersburg, Russia), Director of Polytekhtest Testing Center, e-mail: antonov-mi@yandex.ru;
I.Yu. Pusheva, Peter the Great St. Petersburg Polytechnic University (St. Petersburg, Russia), Candidate of Science (Engineering), Deputy Director of Polytekhtest Testing Center, e-mail: ipusheva@mail.ru;
E.I. Mansyrev, Peter the Great St. Petersburg Polytechnic University (St. Petersburg, Russia), Candidate of Science (Engineering), Deputy Director of Polytekhtest Testing Center, e-mail: enver.mansyrev@yandex.ru;
A.V. Yemelyanov, Peter the Great St. Petersburg Polytechnic University (St. Petersburg, Russia), Engineer of Polytekhtest Testing Center, e-mail: antonov-mi@yandex.ru;
N.M. Antonova, Peter the Great St. Petersburg Polytechnic University (St. Petersburg, Russia), Engineer of Polytekhtest Testing Center, e-mail: antonov-mi@yandex.ru

References:

1. BS 7448-1:1991 Fracture mechanics toughness tests. Part 1: Method for determination of K1c, critical CTOD and critical J values of metal-lic materials, 1991.
2. ISO 15653:2010 Metallic materials. Method of test for the determination of quasistatic fracture toughness of welds, 2010.
3. ISO 12737:2010 Metallic materials – Determination of plane-strain fracture toughness.
4. DNV-OS-F101 Submarine pipeline systems, 2007.
5. BS 7448-3:2005 Fracture mechanics toughness tests. Method for determination of fracture toughness of metallic materials at rates of increase in stress intensity factor greater than 3,0МPа.m0,5.s–1, 2005.

For citation:
Antonov M.I., Pusheva I.Yu., Mansyrev E.I., Yemelyanov A.V., Antonova N.M. Mechanical test method features for measurement of fracture toughness in steel tube weld joints, used in Gazprom Co objects (In Russ.). Territorija «NEFTEGAZ» = Oil and Gas Territory, 2015, No. 8. P. 68–74.

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» Inspection control of welding production at manufacturers of pipe products and equipment for Gazprom PJSC

In accordance with the Schedules of supervisory control of welding production at manufacturers of pipes, components, piping assemblies and equipment for Gazprom PJSC approved on 05.02.2013 and 24.01.2014, from early 2013 till September 2014 supervision control of welding production was carried out at seven pipe products manufacturers and six equipment manufacturers.

Keywords: supervisory control, pipe products, equipment, non-destructive examination, process discipline, violations, comments structure, failure to comply with the requirements, technical conditions.

Authors:

O.I. Neifeld, Candidate of Science (Engineering), Head of the Department for Compliance Control and Permit to Use New Types of Industrial Products, Gazprom Gaznadzor LLC (Moscow, Russia);
V.M. Gomolskiy, Deputy Head of the Department for Compliance Control and Permit to Use New Types of Industrial Products, Gazprom Gaznadzor LLC (Moscow, Russia);
S.P. Sevostyanov, Head of the Welding and Control Laboratory, Gazprom VNIIGAZ LLC (Moscow, Russia);
A.I. Tsyplakov, Sector Head, Gazprom VNIIGAZ LLC (Moscow, Russia)

For citation:
Neifeld O.I., Gomolskiy V.M., Sevostyanov S.P., Tsyplakov A.I. Inspection control of welding production at manufacturers of pipe products and equipment for Gazprom PJSC (In Russ.). Territorija «NEFTEGAZ» = Oil and Gas Territory, 2015, No. 8. P. 64–66.

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» Welding industry condition at Gazprom Public Company. Main lines for development

In this work we considered the condition and technical level of welding industry at Gazprom Public Company, which is highly important during construction, operation and maintenance of main gas pipeline facilities and when producing tubular products. Tasks related to peculiarities of the past and current period are highlighted, in particular the ones related to an ambitious investment program on main gas pipeline facilities construction, and objective necessity to overhaul main gas pipelines, their overhaul scope increases each year. It is noted that quality of welded joints of main gas pipeline facilities should be improved, reliability of welded joints NDT results should be increased, ensurance of required efficiency of welding and installation works and construction rate, reconstruction and overhaul of main gas pipeline facilities of Gazprom Public Company due to regulation in the new regulatory documents of the optimal choice and smart application of methods and practice of automated, machine and manual welding of pipe joints, pipes with fitting and valves, and regulation of scopes and methods of welded joints NDT depending on welding and installation works arrangement and practice applied.

Keywords: welding, welding industry, construction, gas pipeline maintenance, welding practice, NDT of welded joints.

Authors:

Ye.M. Vyshemirskiy, Head of a Group, Gazprom Public Company

For citation:
Vyshemirskiy Ye.M. Welding industry condition at Gazprom Public Company. Main lines for development (In Russ). Territorija «NEFTEGAS» = Oil and Gas Territory, 2015, No. 8. P. 56–63.

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Territorija Neftegas № 8 2015

Read in this issue:

Drilling

Geology

Maintenance and repair of wells

Oil and gas

Repair of pipelines

Transport, storage and processing of oil and gas

Welding