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Description: Issue 57 of Coiled Tubing Times

ISSN 1817-3330 2002 has been published since 2002 3 (057) September 2016 Russian Geophysical MaRket the pRospects of hydRaulic fRactuRinG developMent in tataRstan coiled tubinG technoloGies in east sibeRia the futuRe belonGs to hiGh-tech coiled tubinG seRvices Partner of the issue Packer Service LLC info 7 495 663 31 07 57 3 (057) September 2016 1 2 3 (057) September 2016 3 (057) September 2016 3 4 3 (057) September 2016 Russian chapter of the intervention and coiled tubing association nonprofit partnership coiled tubing technologies development center NP CTTDC 5 1 224 119017 7 499 788 91 24 7 (916) 512 70 54 7 499 788 91 19 -mail info Contact information 5 1 Pyzhevsky lane Suite 224 119017 Moscow Russian Federation Telephone 7 499 788 91 24 7 (916) 512 70 54 Fax 7 499 788 91 19 -mail info 3 (057) September 2016 1 - scientific & practical journal 3 (057) C September 2016 .. ... . - Global Tubing .. ... .. ... .. .. .. ... .. ... .. . .. .. C .. ... - - .. .. ... .. .. ... . () E.. ... . .. ... . .. pResident of editoRial boaRd A. Yanovsky Doctor of Economics Professor Deputy Minister of Energy of the Russian Federation editoRial boaRd J. Attie Vice President International Sales Global Tubing Yu. Balakirov Doctor of Engineering Professor Member of the International Higher Education Academy of Sciences H. Bulyka ditor-in-hief K. Burdin Doctor of Engineering Coiled Tubing Geomarket Technical Engineer Schlumberger R. Clarke Honorary Editor N. Demyanenko Doctor of Engineering Lead Research Scientist of BelNIPIneft RUE Production Association Belorusneft A. Korotchenko Director InTech LLC A. Lapatsentava Director General NOV FIDMASH V. Laptev Doctor of Engineering Vice President of Euroasian Geophysical Society A. Ovsiankin Managing Director Packer Service LLC M. Silin Doctor of Chemistry First Vice-Rector for Strategic Development National Research University Gubkin Russian State University of Oil and Gas E. Shtakhov Doctor of Engineering Deputy Director General RosTEKtehnologii A. Tretiak Doctor of Engineering Professor Member of the Russian Academy of Natural Sciences Head of Oil and Gas Equipment and Technologies Department SRSTU (NPI) V. Voitenko Doctor of Engineering Professor Member of the Russian Academy of Natural Sciences B. Vydrik Director Nonprofit Partnership Coiled Tubing Technologies Development Center R. Yaremiychuk Doctor of Engineering Professor Member of the Russian Academy of Natural Sciences S. Zagranichny Director General Trican Well Service LLP Kazakhstan. the authoR of the pRoject L. Hruzdzilovich (ICoTA-) 119017 . . . 5 . 1 224 . 7 499 788 91 24 . 7 499 788 91 19. -mail cttimes 6000 . 1000 . . 77-16977. . . . . . PuBLiSHER oiled Tubing Times LLC JOuRNAL HAS BEEN PREPARED FOR PuBLiCATiON by Editorial Board of Coiled Tubing Times Journal and The Russian Chapter of ICoTA-Russia ADDRESS OF EDiTORiAL OFFiCE 5 1 Pyzhevski Lane office 224 Moscow 119017 Russia. Phone 7 499 788 91 24 Fax 7 499 788 91 19. e-mail cttimes Edition 6000 copies. The first party 1000 copies. The Journal is registered by the Federal Agency of Press and Mass Communication of Russian Federation. Registration number 77-16977. The Journal is distributed by subscription among specialists of oil and gas companies and scientific institutions. In addition it is also delivered directly to key executives included into our extensive mailing list. The materials the author of which is not specified are the product of the Editorial Board teamwork. When reprinting the materials the reference to the Coiled Tubing Times is obligatory. The articles provided in this journal do not necessarily represent the opinion of the Editorial Board. The Journal offers a cooperation to advertisers and persons concerned. 2 3 (057) September 2016 17- - 10 11 . -. . . . . . . . . . . . (Mongoose Multistage Unlimited) (Plug&Perf on Coil Tubing) . - . . . -- - . Editorial Dear friends a new issue of our journal will soon be at your disposal whether you are on site or in the office Its opening pages invite you to the 17th International Scientific and Practical Conference on Coiled Tubing Hydraulic Fracturing and Well Intervention which is scheduled to be held this year from 10 to 11 November. I look forward to meeting you at our new venue Novotel Hotel in Moscow City. Please come and arrive I promise that you will find it both educational and enjoyable. The Conference Programme will as always be focused on the forefront of the high-technology oil and gas service and its latest innovations. An extensive use of coiled tubing technologies for conveying geophysical tools in the well bore has become an obvious trend in their development. The demand for geophysics keeps growing. This tendency is the subject of a comprehensive article by V. Laptev Russian Geophysical Market to be found in our Prospects column. The strategic prospects of the industry are the main concern of our analysts in the materials prepared by them on the basis of the National Oil and Gas Forum. The most competent experts answer the question What would you call the major driving factors for the global oil industry and for the balance between supply and demand in the world hydrocarbons market . As for the most impressive prospects it is a new project of the FID Group a well-known manufacturer of equipment for high-technology oil and gas service. Top drive drill rig 50 will not leave unimpressed even a diehard skeptic The Technologies column gives as weighty contribution as ever especially in hydraulic fracturing priblematics. P. Demakin the head of the Hydraulic Fracturing Project at LeninogorskRemServis Company dwells upon the prospects of hydraulic fracturing development experts from the Clausthal University of Technology introduce to us the high-end testing frame for coiled tubing our colleagues from Novocherkassk share their experience in using differential sticking control methods while EVS company gives information about new level of wells completion with the possibility of MSF (Mongoose Multistage Unlimited technology) and Packer Service the partner of the issue reports on launching of multistage hydraulic fracturing in horizontal wells. Professor Balakirov from Kiev proposes to do hydraulic fracturing covering two or three layers simultaneously during the realization of the first process algorithm. Please consider our Practice column which is packed with first-hand information from the leading experts of the Russian service companies who present to you the services provided by them. This issue covers the practices of such reputable companies as Ural-DesignGroup the Krasnoyarsk branch of BVT-Vostok. Dear colleagues please accept my congratulations on your professional holiday the Day of Oil Worker Let the heat and light that you deliver to people always make your houses and your hearts feel warm and bright Sincerely yours Ron Clarke 3 (057) September 2016 3 6 17- - 46 88 12 .. ( 3) ( ) 18 ... 22 56 .. .. .. .. 66 .. - 98 .. .. 68 SPE ICoTA 2016 .. .. .. .. .. 100 26 36 .. .. .. .. .. ( - .. ) 74 - .. 86 102 .. --703 40 - (Plug&Perf on Coil Tubing) . 80 - 104 .. ( -- .. -- .. - .. ) ( .. ) 107 4 3 (057) September 2016 CONTENTS CONTENTS CONTENTS CONTENTS CONTENTS 109 - 6 Towards the 17 International Scientific and Practical Coiled th PrACTICE Tubing Hydraulic Fracturing and Well Intervention Conference 74 Coiled Tubing Technologiesof Are Demanded in Oilfields Vankor Cluster and Across East Siberia (Interview with the director of the Krasnoyarsk branch of BVT-Vostok A. Novichkov) 111 PrOSPECTS 12 Coiled Tubing market V. Laptev 118 III (XI ) - Will Develop to High80 The Future BelongsServices Tech Coiled Tubing (Interview with D. Gaidarji Chief Operations Director Deputy at Ural-Design-Group LLC V. Makarov chief engineer at Ural-DesignPNP LLC and A. Kategov chief process engineer at Ural-Design-PNP LLC) 18 Economics Politics Technologies... TECHNOLOGIES 26 The Prospects of Hydraulic P. Demakin OILFIELD CHEmISTry Fracturing Development 100 36 120 ( - ) A. Bairamov P. Belyaev A. Ogorodov . Myrko L. Magadova K. Poteshkina M. Baltayeva S. Kharlanov V. Dedechko mongoose multistage Unlimited New Level of Wells Completion with the Possibility of mSF (mongoose multistage Unlimited Technology) Selection of Aluminum-PolychlorideBased Diverter Composition for Enhanced Oil recovery Operation in Sredne-Khulymskoye Field Formations 102 New Bactericide Agent A. Denisova FLEK-BCI-703 111 COiLED TuBiNG TiMES QuESTiONNAiRE BEAuTY 120 THEOiLFiELDS OF 46 Nelson Perozo Carlos Paz Javier Holzmann Joachim Oppelt (The photos are published by courtesy of the Krasnoyarsk branch of BVT-Vostok) High-End Testing Frame for Coiled Tubings 56 A. Tretyak Y. Rybalchenko S. Lubyanova Y. Turuntaev Differential Sticking Control methods Tubing & 68 SPE ICoTA Coiled Conference Well Intervention & Exhibition 2016 Abstracts NP CTTDC 17- - the 17th international scientific and practical coiled tubing hydraulic fracturing and Well intervention conference 10 11 2016 . (ICoTA-) . (. ). . . ( . 2 . . ). 10 11 . ( .) ( .. ) .. ( .) - ( .) 10 . Intervention Technology Award (ICoTA-). 11 . . 10 11 . . the conference will be held on November 10 11 2016 in Moscow Organizers the Russian Chapter of the Intervention & Coiled Tubing Association (ICoTARussia) Scientific and Practical Coiled Tubing Times Journal and NP Coiled Tubing Technologies Development Center (Moscow) Supported by the Ministry of Energy of the Russian Federation Venue Novotel Moscow City Hotel (Presnenskaya emb. 2 Delovoy Tsentr Vystavochnaya metro station). Please note that the venue has been changed Structure of the event six technical sessions are planned for November 10 11. Topics of the sessions Coiled tubing technologies Latest hydraulic fracturing technologies (multistage fracturing in horizontal wells fracturing plus hydraulic jet drilling nitrogen fracturing coiled tubing fracturing largevolume fracturing acid fracturing plus hydraulic fracturing etc.) Acid Treatments (including matrix acidizing) Radial Drilling Up-to-date well logging techniques including horizontal wells logging conveyance of logging tools using coiled tubing and downhole tractors High-tech well intervention equipment Sidetracking Jet drilling Well service (fishing and milling operations packer setting jobs etc.) New EOR technologies Cement squeeze operations Oilfield chemistry for high-tech oilfield service (hydraulic fracturing chemicals EOR solutions cement squeeze mixes etc.). November 10. Welcome Reception. The Intervention Technology Award established by the Russian Chapter of the Intervention & Coiled Tubing Association (ICoTA-Russia) will be presented to the selected companies. November 11. Round table High-tech oilfield service in the present-day context technologies and equipment . November 10 11. Exhibition. Products and or technologies of the participating companies will be presented there. 6 3 (057) September 2016 NP CTTDC 17- - the 17th international scientific and practical coiled tubing hydraulic fracturing and Well intervention conference -. . . - . . Weatherford Halliburton E - Eriell Group Westor Overseas Holding - -- Serva Group Welltec Jereh Group . . conf 17- . . . conf confreg . E-mail cttimes . 7 499 788-91-24 . 7 (916) 512-70-54 7 499 788-91-19 . Working languages are either Russian or English. Simultaneous interpretation will be provided. The International Scientific and Practical Coiled Tubing Hydraulic Fracturing and Well Intervention Conference is held on an annual basis. It is the Russian longest-standing professional forum for oil and gas services specialists purchasers of hightech oilfield services and manufacturers of oilfield equipment. The conference is attended by the representatives of such well-known Russian and International companies as Rosneft Gazprom Gazprom-neft LUKOIL Schlumberger Weatherford Halliburton Tatneft Bashneft Integra-Services LLC EWS BVT-Vostok Eriell Group Belorusneft PackerService Westor Overseas Holding Frac-Jet Volga Ural-Design- PNP Veteran NOV Fidmash FID Group Serva Group Welltec RGM Jereh Group Borovichskiy Refractory Materials Factory etc. Technical sessions program is traditionally focused on the most advanced technologies. You can get detailed information about the history of the conference at conf At the 17th conference you will have a possibility to communicate with colleagues both in formal and informal surroundings (during coffee breaks standing buffet or evening party). You will be able to discuss timely topics and problems with the specialists of the presented leading oil and gas companies. Our interpreters are always ready to help with linguistic barrier breaking. You will not only gain comprehensive information about the most up-to-date technical innovations of the global and Russian oilfield service markets but also will be able to make new friends. You can sign up to the conference by filling the online application form at conf confreg Information about Sponsorship Packages is available upon request. E-mail cttimes Tel. 7 499 788-91-24 Mobile 7 (916) 512-70-54 Fax 7 499 788-91-19 Website en Contact person Artem Gribov Director of Strategic Development Coiled Tubing Times LLC We look forward to meeting you Organizing Committee 3 (057) September 2016 7 NP CTTDC 17- - the 17th international scientific and practical coiled tubing hydraulic fracturing and Well intervention conference 10 11 2016 ( . 2 . . ) ( .) ( .. ) .. ( .) - ( .). November 10 11 2016 Russia Moscow Novotel Moscow City Hotel (Presnenskaya emb. 2 Delovoy Tsentr Vystavochnaya metro station) Conference topics Coiled tubing technologies Latest hydraulic fracturing technologies (multistage fracturing in horizontal wells fracturing plus hydraulic jet drilling nitrogen fracturing coiled tubing fracturing large-volume fracturing acid fracturing plus hydraulic fracturing etc.) Acid Treatments (including matrix acidizing) Radial Drilling up-to-date well logging techniques including horizontal wells logging conveyance of logging tools using coiled tubing and downhole tractors High-tech well intervention equipment Sidetracking Jet drilling Well service (fishing and milling operations packer setting jobs etc.) New EOR technologies Cement squeeze operations Oilfield chemistry for high-tech oilfield service (hydraulic fracturing chemicals EOR solutions cement squeeze mixes etc.). CONTACTS Tel. 7 916 512 70 54 E-mail cttimes 8 3 (057) September 2016 17- - 10 11 2016 . ( . 2 . . ) 1. . ...................................................................................................... - .................................................................................... ................................................................................................................... - .................................................................................... ................................................................................................................................................................................................................................................................ ............................................................................................................................................................................................................................................................ - ....................................................................................................................................................................................................................... ............................................................................................................................................................................................................................................................... ................................................................................................. .......................................................................................... ............................................................................................................................................................................................................................................................................ ............................................................................................................................................................................................................................................. 2. . 10 11.11.2016 .................................................................................................................... 70 800 . ( ).............. 63 720 . 3- 7% .........................................65 844 . 2009 2015 . 5% ..........................................67 260 . - flash-. ......................................................................................... 11 800 . (18%) ( . 2 . . ) 7 495 705-94-86 3 (057) September 2016 9 aPPliCatioN ForM the 17th international Scientific and Practical CoilEd tubiNg HydrauliC FraCturiNg aNd WEll iNtErvENtioN CoNFErENCE November 10 11 2016 Russia Novotel Moscow City Hotel (Presnenskaya emb. 2 Delovoy Tsentr Vystavochnaya metro station) Please fill in the application form. Mandatory fields Last Name ............................................................................................................................................................................................................................................................. First Name ............................................................................................................................................................................................................................................................. Position ..................................................................................................................................................................................................................................................................... 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Please select your participation option conference exhibition. 10 11.11.2016 CoNFErENCE Registration fee For delegates...................................................................................................................................... 1490 For reporters (Non-advertizing reports)......................................................................... 600 The nature of the report is defined by the Program Committee of the conference 3 or more participants from one organization have a 7% registration discount Registration fee for one person ........................................................................................... 1380 The participants of the conferences in 2009 2015 have a 5% registration discount Registration fee for one person ................................................................... ....................... 1410 Registration fee includes participating in the technical sections coffee breaks lunches dinners and evening reception touring of the exhibition as well as getting conference handouts and presentations of reports on a flash-drive. All prices include VAT Please select your participation option and registration fee Option Delegate of the conference Delegate and reporter of the conference Correspondent participant of the conference Price Novotel Hotel Address Russia Novotel Moscow City Hotel (Presnenskaya emb. 2 Delovoy Tsentr Vystavochnaya metro station) Reservation service 7 495 705-94-86 10 3 (057) September 2016 3 (057) September 2016 11 550.8. 338.8 RuSSiAN GEOPHYSiCAL MARKET .. - v. laPtEv First vice-president of Euroasian geophysical Society -Eago director of geophysical tools manufacturing in Novtek New technologies llC 2015- . . . [1 2 3] Schlumberger Halliburton Baker Hughes Weatherford. . . . 1 2 . Halliburton Weatherford Baker Hughes ( ) 1 . Schlumberger . Schlumberger ( 530 2015 ) . 8- . . Schlumberger The year 2015 has become a landmark for Russian geophysical market in all respects. Let s consider the most important aspects of this process. import substitution. Previous market researches described risks associated with activity of geophysical service leaders - Schlumberger Halliburton Baker Hughes Weatherford in our country. There was a threat that these corporations would take over Russian companies with unpleasant consequences for Russian geophysical science education and equipment manufacturing. This threat was enhanced by examples of successful acquisition of Russian companies Petroalliance Tyumenpromgeofisika Siberian Geophysical Company Krasnoyarskneftegeofizika Pomorneftegeofizika Geofit Kiev Logging Equipment Experimental Design and Manufacturing Center Orenburgneftegeofizika and failed attempts of acquisition of Gazpromgeofizika Noyabrskneftegeofizika and Bashneftegeofizika. We all know the story of legendary Kiev Logging Equipment Experimental Design and Manufacturing Center and Geofit. Tables 1 2 present positions of main geophysical market majors. There are no Halliburton and Weatherford in this list Baker Hughes (Orenburgneftegeofizika) is most likely to leave the group of companies with annual revenue more than 1 billion rubles. Schlumberger is still a leader but it is under growing pressure from Russian companies TNG-group Rosgeologiya Gazprom-Georesurs Bashneftegeofizika. In order to remove Schlumberger from leading position it is necessary to acquire Schlumberger s offshore drilling service ( 530 million in 2015) in Russian offshore sector. This will move Schlumberger to the 8th position. No doubt from technical point of view above-listed companies are capable to solve this task. In response to sanctions against state companies Rosneft and Gazprom that are responsible for shelf development it is necessary to provide Russian service with priority access to offshore 12 3 (057) September 2016 . 1 Tables 1 . - MWD LWD . . () 2 Tables 2 . . . . 3 5%. ( ) . . . . . 1 2 . 1 operations and liquidate Schlumberger s monopoly for this service. In USSR these operations were performed successfully by Gazpromgeofizika. As for hi-tech tools MWD LWD there is no longer a technological gap between Russian and foreign companies in these tools. It should be noted that sanctions by USA and European Union made positive impact on breaking dependency of Russian fuel and energy industry on foreign service. Synergistic effect of sanctions and counter-sanctions (import substitution) gave a push start for Russian companies to retake control over its own market. However there is a positive impact of presence of world-leading geophysical companies in our market. These companies demonstrated lessons 3 (057) September 2016 13 PROSPECTS . 2010 2015 30%. 28 . -- . 2015 - 30 . 20 . 15 . 2015 (. 2). . . . . . . . HF CT Well logging Seismic survey 1 Figure 1 Development of Russian geophysical market on how to compete organize economic and innovative activity carry out staff selection and training interaction with customers small business and many other issues. Foreign presence is surely useful for our market but only to a certain extent. USA and China experience showed that 3 5% level is sufficient for this purpose. Therefore the threat of intervention of foreign companies into Russian geophysical market is eliminated recovery process has become irreversible. Russian geophysics recovered its status in the three leaders of geophysical market USA Russia and China. All required background for this recovery process is prepared. Market growth and assets consolidation. As can be seen from tables 1 2 and fig. 1 geophysical market shows steady growth. Over a period of 2010 2015 growth rate was approximately 30% on the average. World energy crisis oil price downturn to 28 per barrel ruble weakening sanctions from USA an EU couldn t influence this trend. The key market growth drivers were increase in horizontal drilling volume and research of unconventional resources shelf development creation and mass manufacturing of hitech tools diversification of range of service as well as sanctions from USA an EU. Leader by growth of service scope in 2015 was TNG-Group that reached revenue of 30 billion rubles two companies Geotek Holding and Rosgeologiya reached 20 billion rubles GazpromGeoresurs and Bashneftegeofizika reached 15 billion rubles. One of the most significant events in 2015 was government decision about consolidation of isolated geophysical assets with state-owned stakes under one state geosciences holding Rosgeologiya (table 2). In comparison with other companies this holding concentrates the most powerful assets of offshore geophysical capacities. In seismic sphere this companies are Sevmorneftegeofizika 14 3 (057) September 2016 . 2015 - () - . () (). 70% . 25 30% . . . 1. . . . 2. (3D- LWD - ). . 3. 2015 80 85 . 2020 100 110 . 2010 2015 1 6 5 5 . 2020 650 2015 1900 . 4. . Schlumberger Sevmorgeo and Dalmorneftegeofizika in offshore well logging industry Kaliningradneftegeofizika and Krasnodarneftegeofizika. These assets in conjunction with import substitution policy will make possible to force foreign logging service out of Russian offshore industry the same way as it happened in China. Another important advantage is an integration of this holding with state geopolitical toolbox at the world energy market. The future will show whether holding with strong government support will become a top driver for improvement of efficiency and competitive ability of Russian geophysical complex in the country and the world. Establishment of large state corporate and independent geophysical companies in Russia will provide new instrumental platform for closer equal cooperation with Russian oil and gas companies thus enabling service price stabilization and more clear predictable and comfortable market for fair companies. Diversification of service. One of the key drivers for geophysical market growth is the expansion of range of services that are offered by geophysical companies to oil and gas companies. In 2015 the number of companies with coiled tubing (CT) service increased Kogalymneftegeofizika Bashvzryvtekhnologii TNGGroup Bashneftegeofizika Yamalpromgeofizika Yamalpetroservice and Gazprom-Georesurs. Many companies consider this business as the first step into the market of up-to-date technologies for enhanced oil recovery hydraulic fracturing (HF) and multistage hydraulic fracturing (MHF). In contrast to geophysical market 70% of HF market is controlled by service companies from countries that applied sanctions against Russian oil and gas industry. If foreign companies simultaneously leave the market the impairment to the country would be a drop in oil production by 25 30%. Ministry of Energy and Ministry of Industry and Trade claimed HF technologies and manufacturing of corresponding equipment to be the most urgent tasks in the list of top-priority directions of import substitution. At present time government provides support to Russian companies that develop HF service and equipment manufacturing. Entry of geophysical companies into HF MHF and CT market is promising due to the number of reasons Government will provide the most preferential treatment for those companies that decided to enter this market until lifting of sanctions. No one knows what will happen after lifting of sanctions. That is why it is necessary to hurry up. The main source of information for effective application of HF and MHF is geophysical methods (3D seismic survey vertical seismic profiling positioning advanced mud logging LWD cross-dipole acoustics perforation ecological and HF monitoring). This gives the opportunity to provide more expensive integrated turnkey services. 3 (057) September 2016 15 PROSPECTS Halliburton Baker Hughes Weatherford . 5. . 7 10 . . . . . . . 25 30 . 2 3 . . 2015 -. - LWD c ( ) LWD c ( ) ( ) . . . . In 2015 HF MHF and CT market volume is estimated at 80 85 billion rubles with growth prospects up to 100 110 billion rubles in 2020. In physical terms the volume of HF operations increased by 1 6 times during 2010 2015 period MHF volume increased by 5.5 times during the same period. MHF market is expected to grow from 650 wells in 2015 to 1900 wells by 2020. HF MHF services make a direct impact on production rate that is why this market is stable and financially reliable. Schlumberger Halliburton Baker Hughes and Weatherford are the world s most active companies working in this business. They invest significant funds in development of these technologies. Staffing requirements may be filled by transfer of experienced personnel from foreign companies that leave Russian market. In foreign companies the average age of existing fleets is 7 10 years. In this respect Russian companies equipped with new up-to-date machinery and experienced personnel have a competitive edge along with government support. Russian HF MHF and CT service is represented by affiliated companies of oil companies Surgutneftegaz Tatneft and Rosneft. The first two companies fill the need for service by its own forces. TagraS-Holding LLC executes orders from other oil and gas companies apart from servicing Tatneft. Only a third of Rosneft needs for HF and MHF service are filled with its own subsidiaries. In conclusion HF MHF and CT market is a promising sector for Russian geophysical companies the conditions of entry into a market are highly convenient. Window of opportunities for market is estimated at 25 30 billion rubles of the annual revenue during 2 3 years until lifting of sanctions. geophysical tools manufacturing market. Many new hi-tech tools entered the market in 2015. The tools included multi-pole lateral logging tool cross-dipole acoustic tool LWD tools with hydraulic telemetering system (OJSC Research and Production Company Geofizika ) LWD tools with electromagnetic telemetering system defect detection tool for multi-string wells (Group of Companies VNIIGIS) new generation of tools with neutron generator for a long-term operation (Federal State Unitary Enterprise VNIIA) and many other tools. It can be stated that all needs for logging tools are filled with products manufactured in Russia. One of the notable tendencies of geophysical market is the establishment of integrated companies that comprise service science and manufacturing. On the one hand tools manufacturers get involved into service business on the other hand service companies acquire its own science and manufacturing assets. For instance half of the 2.6 billion rubles of the annual revenue of group of companies VNIIGIS comes from providing services. ZAO Bashvzryvtekhnologii is also positioned as a successful market player because apart from development and manufacturing of perforation 16 3 (057) September 2016 2 6 . . . . - . 2014 . ( ). 40 2015 25 . 40% 20% . -- LWD . ITTEK . 2015 . (). . . . - . tools it performs a wide range of logging and coiled tubing services with HF and MHF service in prospect. Neftegazgeofizika LLC the main manufacturer of thermopressure-resistant well tools performs hightech services on magnetic resonance logging carbondioxide logging and other methods. The largest service companies TNG-Group Bashneftegeofizika Gazprom-Georesurs Rosgeologiya and other companies create and develop its own research and tool manufacturing centers. New experiment on the evaluation of new forms of government support of innovative activity has been started in 2014 in geophysical tools manufacturing market. Ministry of Industry in Republic of Bashkortostan supported the first largest geophysical cluster Kvant (Group of Companies Kvant ). This cluster includes 40 small medium-sized and large businesses with the overall revenue of 25 billion rubles in 2015. Kvant companies provide 40% of Russian market needs for geophysical tools and equipment and 20% of service market. In terms of different government import substitution programs Group of Companies Kvant develops hi-tech machinery for LWD unconventional resources HF MHF recovery factor monitoring and other tasks. In particular in cooperation with Belorussian partners Group of Companies Kvant created CITTEK company that provides manufacturing and assembly of equipment for HF and CT in Ufa. It is planned to create new service company that will use this equipment. In conclusion it should be noted that under conditions of oil and gas prices downturn world energy crisis and ruble weakening in 2015 Russian geophysical market carried on progressive growth and reached several strategic achievements. Sanctions from USA and EU as well as counter-sanctions from Russia (import substitution) played a positive role in this success. Conclusions. Russian geophysical market recovered its status in the three leaders of geophysical market USA Russia and China. The threat of intervention of western or eastern companies into this high-tech industry is eliminated. Short-term development objectives for Russian geophysical service are recovery of previous positions at Russian offshore industry development of MHF-CT service and return to the world service market. REFERENCES 1. .. . 2014. 2. . 16 18. 2. .. . 2013. 1. . 12 16. 3. .. . 5. 2013. . 7 14. 3 (057) September 2016 17 PROSPECTS ... Economics Politics Technologies... 2016 III . .. . . In April 2016 the Expocentre in Krasnaya Presnya (Moscow) housed the III National Oil and Gas Forum. The main agenda of the event was defined in the opening speech delivered by D.A. Medvedev the Chairman of the Russian Federation Government and included Priority issues of import substitution enhancing investment prospects of the Russian fuel and energy industry implementation of stateof-the-art technologies and energy infrastructure improvement . The members of one of the key discussions were asked to answer the following question What would you call the major driving factors for the global oil industry and for the balance between supply and demand in the world hydrocarbons market Here are the opinions given by competent experts. arkadiy dvorkoviCH Deputy Chairman of the Russian Federation Government As I see it there are three major factors. First it is the overall global economic environment. While today we are discussing the political situation and market strategies the . demand and supply remain the fundamental factors . which depend on the rate of economic growth and the course of development taken in different regions. Over the recent years in spite of the continuing crisis recovery in various countries the rates of growth have still been much lower than they used to be during . the previous decades. This holds down the demand for energy resources. The development of the global energy industry is also under the influence of the energy efficiency policy which was implemented . by most of the advanced . countries in the period of high prices for energy resources. Such policy has dampened to a significant extent the demand for hydrocarbons. No doubt . another contribution has . been made by the policy . of transition to renewable Various government policies energy resources. domestic production support which The second major factor . is sometimes cost-inefficient cause a is the policies pursued shift in oil and gas market balance. by certain countries and companies in relation to new technologies and . breakthrough technologies. On the one hand such policies result in hydrocarbons being partially replaced . with new sources of energy. Although slow this process . keeps going. On the other hand there is a reduction in hydrocarbons production costs with new technologies ensuring cost-effective decisions for producing both oil and gas. Consequently this changes the equilibrium . price and in general the market situation. . 18 3 (057) September 2016 Nor would I disregard the political factor. Various government policies including those in relation to . energy diversification or domestic production support which is sometimes cost-inefficient and involves additional expenses for consumers cause a shift in oil and gas market balance. We don t think this situation is transparent enough. Consumers are given only partial information such misrepresentation should be . reduced to minimum. . vagit alEkPErov CEO LUKOIL I can see a number of factors. First is the breakthrough in . technologies. Second is the transfer of oil production centres to new regions in particular to consuming . regions including in the USA. Third is a combination . of incompatible circumstances with political events in the Persian Gulf which used to cause increase in . oil price having today the opposite effect and making certain countries scale up production in order to cover the budget deficit and raise funds required inter alia for arms procurement. aleksandr SHokHiN President RSPP As I see it everybody agrees that there are three major factors. One of them is no doubt geopolitics. Another factor is sure to be connected with economic situation the . demand and supply balance. Although we say that the equilibrium oil price in view of the current global economic situation should be 60 to 70 dollars per . . barrel it is unlikely to be the true equilibrium price. We don t know exactly what is going to happen at the . Chinese market whose performances are not as high as they have been recently forecast. Eighteen months 60 70 ago the leaders of G20 agreed that the rate of the global - . economic growth would be plus two percentage points per annum as compared to the existing trend. Today it is obvious that no . such dynamics is being observed. Therefore there will be no additional oil demand with the oversupply already in place and potential overstock to . be expected this year. There are also . . technology factors also technology factors energy efficiency energy efficiency shifting away from shifting away from hydrocarbon-based hydrocarbon-based economy as a long-term trend and economy as a long-term technological breakthroughs which have trend and technological . already turned some countries from importers into exporters of hydrocarbons. breakthroughs which have already turned some countries from importers into exporters of hydrocarbons for example the United States. This is a long-run factor and its impact on the hydrocarbons market will continue to grow. aleksandr korSik CEO and Chairman of . the Management Board Bashneft Joint-Stock Oil Company I believe that the first factor is the shale oil . in the USA. Another factor which we currently give little thought to is electric automobiles. This factor 3 (057) September 2016 19 PROSPECTS may pop up suddenly . against all expectations and calculations and . although it is not thought . to happen soon I still Factor which we currently have some fears. A third . factor is politics. It seems give little thought to . to me that some countries is electric automobiles. are ready to suffer losses provided their . neighbours suffer too. aleksandr Novak Minister of Energy of the Russian Federation To cut a long story short these are the political factor the implementation of new breakthrough technologies investment solutions cutting-edge methods of oil production and energy . consumption worldwide and energy-efficiency measures. Another factor is economic growth or economic slowdown both of which have a significant . impact on the demand and supply balance at the oil and energy resources market. yury SHaFraNik Council Chairman Union of - Oil & Gas Producers of Russia Over the recent 5 7 . years we have seen profound changes in the global power industry. The energy world map can be claimed . to have been updated. The reasons are the new breakthrough technologies dramatic technological . progress covering all aspects and expansion of 2000- the resource base. Let me remind you that in the early noughties international energy agencies made forecasts for a potential production peak with its . subsequent decline on the account of insufficient . resources. However the implementation of new technologies has proved such forecasts to be wrong. Renewable energy resources which I was skeptical about some fifteen years ago represent 28% of the 28% 17%. current energy balance in Germany and 17% in the USA. Energy efficiency is increasing in all of its aspects. . Gas and electric vehicles continue to gain ground and while it is far from being a universal process its predecessors are obvious. The usage of gas hydrates . . is another prospect. Japan is planning to start their 2018 commercial production as early as in 2018. . The USA over less than a decade have turned from a major importer of hydrocarbons into a country with surplus hydrocarbon resources. China . notwithstanding the forecasts for a slowdown in the growth dynamics has become and remains the largest . consumer of energy resources. Today the main tendency is the oversupply of hydrocarbons the transformation of a seller s market into a buyer s market and the shift in priorities - from the focus on resources and raw materials to . technologies and innovations. Figuratively speaking it is as if two poles the North Pole and the South . - Pole have swapped places. And it has taken only five . to seven years for such tectonic changes to occur. . The world has entered into a new cycle of economic development. III Based on the III National Oil and Gas Forum Analysis Team of the Coiled Tubing Times Journal 20 3 (057) September 2016 3 (057) September 2016 21 22 3 (057) September 2016 3 (057) September 2016 21 25 2016 . . . . . . 30 150 . - 50 . . . . . . 22 3 (057) September 2016 . . . - . ISO 9001 I. . . . . . . . . - . SAGD. - 3 (057) September 2016 23 PROSPECTS 0 75 . . . . . . . . . - . . . 50 . .. . . 50. . 50 . . . - . . . . . 24 3 (057) September 2016 . 50 . . - . . . . . . . . . . . . . . - . 10 20 . . . . . . 3 (057) September 2016 25 PROSPECTS the prospects of hydraulic fracturing development .. - P. dEMakiN Head of Hydraulic Fracturing Project leninogorskremService llC tagras-remService . . .. . . . . . . TS Bioxan . . Hydraulic fracturing technology is currently in high demand due to the fact that its effectiveness is comparable to the effectiveness generated by the process of new well drilling. Sometimes hydraulic fracturing is even more efficient than the latter. Moreover it is two or even more times cheaper to perform hydraulic fracturing than to drill a new well. Today hydraulic fracturing technology is well-developed and customers are interested not just in hydraulic fracturing itself but in the process of its execution under various conditions including geological and formation conditions etc. Fracturing techniques that take into account all mentioned conditions now come to the foreground. That is why the competency of the company that provides hydraulic fracturing services as well as its tools and technologies stack are now gaining more and more significance. Tagras-RemService pays great attention to available technologies. We keep track of new developments presented at various exhibitions in journal articles and discuss them with our colleagues and customers. We always try to be at the cutting edge of innovations application. The material that will be presented below contains only a small part of our Company s expertise since it is impossible to demonstrate everything in a journal article of limited volume. In the focus of this publication we put a combined technology of proppant and acid fracturing as well as fracture height limitation technologies and techniques that replace linear gel with TS Bioxan chemical. all mentioned technologies are designed to help customer achieve maximum levels of oil production from the reservoir selected for treatment. 26 3 (057) September 2016 1 slide 1 Russia has unique energy resources. The main customer of LeninogorskRemService LLC is Tatneft OJSC. But our Company has operational background in Povolzhski Region as well. Currently every oil company is trying to extract residual oil reserves more effectively. Meanwhile around 60% of total in-place oil reserves are concentrated in carbonate reservoirs. Development of such oilfields is associated with lots of problems that cause troubles during exploitation of wells and can lead to inability of unlocking full potential of wells. Hydraulic fracturing is now one of the most efficient enhanced oil recovery methods. If there are water-saturated areas situated near the interval to be treated or there is a fractional cement stone proppant hydraulic fracturing or acid fracturing should be performed carefully due to the risk of fracture breakthrough into a watered layer. In such cases it is appropriate to use the technology of high-volume matrix acidizing which should be performed under a pressure not exceeding reservoir breakdown pressure. I.e. only the matrix (pore volume) of reservoir should be treated. At the first stage of high-volume matrix acidizing an injection test is performed. Specialized software determines reservoir breakdown pressure on the basis of injection test results. The determined value should not be exceeded during acid treatments. The technology of acid fracturing involves sequential injection of gel and acid. Gel is used for blocking natural cavities in carbonate reservoir while acid composition injected after has time-lagged reaction time and provides deep chemical treatment of low-permeability formation intervals. Due to low formation pressure and the lack of formation energy 1 . . . 60% . . . . - .. ( ). . 3 (057) September 2016 27 TECHNOLOGIES 2 . . . . . . . . . often it turns out that carry-over of reaction products is rather slow. As a result the increase of well flow rate is strongly correlated with the rate of fractures cleanout. In order to deal with that we use nitrogen during the stage of gel injection. Aerated fluid significantly increases permeability and conductivity of fractures. The mentioned treatment leads to break-up of limestone and dolomite which form water-soluble reaction products. This technology is successfully used in the wells of our customers. slide 2 In order to perform high-volume matrix acidizing low flowrate (50-100 liters per minute) is required. Pumping equipment owned by our Company allows to perform operations with a flowrate of 200 liters per minute. But there is a risk of premature failure of pumping units. To address this issue we have recently purchased a low flow pump that allows to maintain flowrates of 50 liters per minute. We use this pump during high-volume matrix acidizing operations. Thus we increase the quality of works and treatments efficiency. In order to control such operations one needs just a control station. Preparation of gelling agent and injection 2 (50 100 ). 200 . 28 3 (057) September 2016 3 50 . . . . . of chemical additives can be performed using a chemical dosing station which is more fuel efficient in comparison to a blender. slide 3 The major part of oil reserves owned by Tatneft OJSC is constrained within carbonate reservoirs. As it was previously mentioned the main EOR technology suitable for carbonate reservoirs is hydraulic fracturing. After acid fracturing or hydraulic fracturing of high-permeability carbonate reservoirs as well as after elimination of formation contamination one can observe a substantial production increase. But this effect can have short duration due to a limited volume of formation being treated. That s why there is an idea to combine the technologies of acid and hydraulic fracturing since such combined action will have a synergy effect on formation. High potential of combined action of acid fracturing and conventional (proppant) fracturing is stipulated by the fact that created fractures are fully propped that allows acid to penetrate far into formation matrix. I.e. the treatment is moved deep into formation thanks to a displacement profile (fracturing fluid with non-Newtonian properties is one of the most 3 . . . . . 3 (057) September 2016 29 TECHNOLOGIES 4 ( ). . . 5 32 3 . ( 3 ). . effective materials for profile adjustment). In order to implement the technology of combined usage of acid and conventional fracturing it is necessary to have state-of-the-art high-tech and reliable equipment. Since during such operations two incompatible types of fracturing fluids are used it is required to exclude the possibility of their mixing as well as to provide easy means of recovering aggressive fracturing fluids. Here one of the most important factors was our effective cooperation with NOV FIDMASH which resulted in efficient application of the existing equipment for conducting the combined acid and hydraulic fracturing operation. In the framework of pilot program a combined technology was used at one of the wells of Tatneft OJSC. A total of 5 tons (the figure specifies the amount of 3 tons) of proppant and 32 cubic meters of acid was injected into the well. The outcome of this operation was greater than that generated by a sole acid treatment. slide 4 One of the promising directions is oil recovery from low-permeability Mendym-Domanic deposits. The first such operation was ineffective. We got a wellbore screenout during hydraulic fracturing operation. 30 3 (057) September 2016 3 5 4 - . . . . . . After that we changed the fracturing design. In order to increase permeability we perform acid fracturing. Only after this operation is over we proceed to conventional fracturing with the application of linear gel alternated by low-mesh proppant packs. It should be noted that in order to prevent screenouts it is required to maintain high injection rates. slide 5 One of the most substantial problems is watering of high-permeability NizhnePashiyskiy deposits and close placement of potentially productive horizons and water-bearing formations. To address this issue we successfully apply the fracture height limitation technology that includes mini-fracturing operation with injection of mixed-mesh proppant and linear gel. This approach allows to screen highpermeability channels that connect the target zone with underlying water-bearing formations and to increase the drainage radius. It results in oil production increase and watercut decrease. The confirmation of fracture height limitation was obtained with the help of geophysical 5 . - . 3 (057) September 2016 31 TECHNOLOGIES 6 . . . 2015 2016 67 52 . logging and marked proppant. The described technology was tested in 67 wells during the years of 2015 2016. The desired effect was obtained in 52 of them. slide 6 In the wells with low formation energy usually there are complications during pre-frac and post-frac operations. They are related to backfill of underlying formations and post-frac proppant cleanout. In order to perform the above operations it is necessary to use bailer. The possible solution to this problem can be connected with the application of two-packer assembly during hydraulic fracturing. When conducting hydraulic fracturing in high-permeability formations there is a probability of post-frac proppant backflow. To prevent this threat we started to use RCPproppant. The technology of creation of the so-called artificial barrier as well as the combined acid and hydraulic fracturing operations in carbonate reservoirs were previously described. 6 . . . . RCP-. . 32 3 (057) September 2016 7 7 . - . . . .. . . . . slide 7 Oil reservoirs often have a nonuniform permeability to oil and water while their wettability points to water formations. During post-frac wells completion and following oilfield development a number of difficulties may arise due to entrapment of water by the rock and resulting blockage of oil. The water is filtered into a bottomhole zone where it displaces oil and pushes it back into formation. The latter is then confined by capillary forces within formation pores. During further well completion the flow of oil out of formation stops since the underbalanced conditions between the bottomhole zone and formation cannot overcome capillary pressure that confines water inside low-permeability reservoirs within bottomhole formation area. Such a well turns into a marginal one. If the proppant has hydrophobic characteritics it can repel water. Water inside a formation is displaced by oil and pushed out of small formation pores into the bigger ones. Water can be removed from bigger formation pores during further well completion. In well used for formation pressure maintenance it is better to use hydrophilic proppant which will allow to decrease surface pressure thus increasing intake capacity of well. Currently laboratory testing of such proppant are being performed. 3 (057) September 2016 33 TECHNOLOGIES 8 8 - . . - . . Bioxan . . 2016 . 12- . slide 8 A number of marginal wells and wells with watered high-permeability formations of NizhnePashiyskiy horizon is increasing. That is why we have problems during selection of well candidates for hydraulic fracturing. During hydraulic fracturing of wells that have closely-spaced waterbearing horizons or thin barriers between them a linear gel can be used instead of crosslinked gel used during standard fracturing operations. The drawback of linear gels is their low sandlifting capability which limits maximal proppant concentration and can lead to potential screenouts. That is why the range of linear gel application is quite limited. On the way to solve this problem we found a completely new fracturing fluid system called Bioxan. It is a polysaccharide self-hydrated gelling agent which sand-lifting capability is five (5) times higher than conventional linear gels. In the framework of pilot development program we plan to perform hydraulic fracturing with the application of Bioxan fracturing fluid at the wells of Tatneft OJSC. The works are scheduled for Q2-Q3 of 2016. This material is prepared on the basis of report made during the 12th NOV FIDMASH s Consumer Conference. 34 3 (057) September 2016 3 (057) September 2016 35 Mongoose Multistage Unlimited New level of wells completion with the possibility of MSF (Mongoose Multistage Unlimited Technology) .. .. .. - .. a. bairaMov technical Sales Manager EWS P. bElyaEv director for business development EWS a. ogorodov drilling & Well intervention department Well intervention Section gaspromneft StC . Myrko lead engineer EWS () . . () . ( ) . - - 14 - () Mongoose ( ). NCS Mongoose Multistage Unlimited ( ) . introduction Multistage fracturing (MSF) is acknowledged to be as one of the main methods of formation stimulation in Russian Federation. The main purpose of this method is to provide highly conductive fractures in oil and gas reservoir throughout the wellbore horizontal section. For this the sequential series of hydraulic fracturing (frac) are made the result of which is the hydrocarbons maximum production rate. Over time the oil and gas companies in Russian Federation are becoming more demanding in technical and technological parameters of MSF in terms amount of stages the maximum depth (particularly in its horizontal part) possibility of re-fracturing and control of intervals ports after start of production and more. Therefore Gazpromneft-Khantos LLC and Gazpromneft NTC LLC in partnership with EWS LLC during the last 14 months have been conducting pilot projects on MSF Mongoose technology with sliding sleeves (with the possibility of repeated opening closing). NCS Mongoose Multistage Unlimited technology (official distributor in Russia is LLC EWS ) is acknowledged to be as an alternative to the current methods of MSF with ball drop completion. general information about NCS Mongoose Multistage unlimited technology In this technology BHA for intervals separation running on CT and sliding sleeves or sand jet perforation (SJP) are combined which allows multi-stage frac during well completion in one run and more effectively than any other method allows. NCS Mongoose Multistage unlimited technology features CT string running allows using multiple packer 36 3 (057) September 2016 () . . . . . . . ( ) . . . 1 Mongoose Figure 1 Mongoose BHA run for isolation intervals unit for frac and sleeve shifted out mechanically. Multiple packer unit shifts the sliding sleeve out on each stage in open position. This combination allows canceling pumping plugs and balls shifting sleeves. Sliding sleeves run in the liner during well completion and set on the planned depths for fracturing. These sliding sleeves can be cemented together with the liner so there is no need to install the annular packers to isolate frac intervals. Sliding sleeves have the same internal diameter and strength characteristics as does the liner and come with a top sub to rig up liner into BHA lower end is a nipple thread the top is sleeve. A distinctive technology feature is the fracturing if there is a lack of an open sleeve injectivity (for geological reasons) or the need to add a stage without additional trip. Also the important factor is the ability to test the plug leakage packer after setting up and before sleeve opening allowing to be assured after sleeve shifting that during injection test the fluid goes to the formation rather than leaking through the plug packer. Otherwise the complications might occur due to fracturing fluid leakage into the underlying formation. () Controlled optimization of MSF technology completion The technology of controlled optimization of MSF technology completion is in the process of pressure monitoring downhole during sequential fracturing stages in real time. An important system 3 (057) September 2016 37 TECHNOLOGIES . . Mongoose 20 101 3 114 3 . 2016 30- - - . 30 4586 1500 . Mongoose ( ) 40 . 6 . Mongoose . . ( ) . ( ) 600 3. ( ) . 2 Figure 1 cT Fleet rig-up feature is that in addition to its core values namely diagnosis and recording of downhole pressures and temperatures above and below the packer the system makes possible to optimize the fracturing fluid formulation using real data on heating and cooling in the fracturing fluid downhole conditions during frac operation and after its completion. the task More than 20 well operations in 4 and 4.5 liners with sliding sleeves and or SJP were done with MSF Mongoose technology in Russian Federation. In particular a record for Russian Federation 30-stages MSF was done in June of 2016 with sliding sleeves at South Priobskoye field of Gazpromneft-Khantos LLC. The customer had a task to provide 30 stages MSF in well total length of 4586 m with a horizontal section of length 1500 m which also includes the task of get bottom of the extended horizontal section logging operation on CT string. Also in connection with the Mongoose technology features when the transition from one stage to another (packer reseating after frac pulling to the next interval frac sleeve positioning packer seating and sleeve opening) takes about 40 minutes but the main factors for a new well to 38 3 (057) September 2016 50 8 . . . 50 8 () . 30- 30 . 1179 ( 40 ). 20 - ( ). 2 . ( ) . 7 21 . 3 . 50 8 . . operate a large number of MSF is the speed of each frac stage namely preparation for it. Thus the additional task was to carry out additional 6 frac per day. That is not critical for most Mongoose technology but limited only by frac fleet work. These parameters are also critical in terms of the speed of work and bringing well in operation. Thus EWS LLC also provided services for coiled tubing and fracturing (with NewTeck Well Services Ltd.) for maximum co-operation between the two services. To ensure uninterrupted supply of technical fluids for hydraulic fracturing it was used 600 m3 (with the possibility of heating in winter) tank pool. Also the preparation method to carry out hydraulic fracturing was developed in advance (together with the customer) to avoid possible downtime including uncoordinated actions. While designing this well by the engineering department of EWS LLC the income calculations were carried out in the software which confirmed the need for a coiled tubing 2 string. This string allows reaching the bottom and holding the opening the lower sleeves without using downhole tools that provide additional traction. This simplifies the main type of work. Also using 2 coiled tubing string the necessary fluid flow during critical pressure increasing while fracturing (screenout) and necessity for washing out the wellbore from proppant. results and conclusions Because of this work we can say that 30-stages MSF has been successfully done all 30 sleeves were shifted. It was pumped 1 179 tons of proppant (approx. 40 tons per stage) during all stages. One of the achievements is also done the first 20 frac stages per one trip (without tool redressing). It was 2 times trips in total to total amount of stages. Additionally cement bond log tools running on CT and Downhole GR-Density Fault Detectorwas made (before frac) to measure the horizontal section quality of the well cementing. During last stages the 7 stages of hydraulic fracturing were held in 21 hours which means achieving client objectives. During operation 3screenouts occurred that have been successfully cleaned out without any additional trips. The results of this well-operation allows a new level of wells completion with the possibility of MSF with maximum increasing of formation oil recovery factor and its economic efficiency rather than limiting the frac stages restricting access to the wellbore after frac necessity of additional runs maximum depth and other factors related to well completion. 3 (057) September 2016 39 TECHNOLOGIES 1 plug&perf - 2 (plug&perf on coil tubing) . .. (Plug&Perf) - (.) (ballsleeves) 3 2016 - Plug&Perf - . 1) 2) 3) (). . 3 4- 4 . 102 89 . . . . . - 450 89 () 40 3 (057) September 2016 4 plug&perf ( ) 9.50 11.00 (14.1 16.4) - - inch inch () () 3 . inch () Min Max . . . inch inch inch () () () 4 (101 6) 3.48 (88.3) 3.55 (90.1) 3.19 (81.0) 15.2 (386.0) Baker 10 Owen 250 F (121 ) 10 psi (68.9 ) (100 ) 146 . 200 . 102 ( ) . 5 Plug&Perf ( 4- 5 ). 1 . 100 ( 2016 ) 1. ( ) . 2. 1- (3 .). . 3. ( 85 ) . 4. - 2- . . 5. . 4 4- 3- (4- ). 6. 3- (3 85 ) . 7. ( ) . 3 (057) September 2016 41 11.06.2016 (4- ) Plug&Perf ( ) . () - . (102 114 ). . ( ). . . - . ( ) ( ). ( ). . - . Plug&Perf . - . Plug&Perf (102 ) (monobore). 2 2-80-2440 82 . 2016 3 . 146 102 . 102 102- . Plug&Perf. 102 146 . 146 . 2016 ResourceWellCompletions. 42 3 (057) September 2016 5 ( ) . ResourceWellCompletions 6 . . 6 ( ). API. (ZoneStriker) . . . NEWS COLuMN uPTADE DAiLY NEWSLETTERS WEEKLY OiLFiELD SERViCES iNNOVATiONS REViEWS MONTHLY NEW JOuRNAL iSSuE QuATERLY 3 (057) September 2016 43 - . - - . ( 20 500 ) . . . - . . . . . . . . . . . . . . - . 44 3 (057) September 2016 ( ) .. .. - . ( DS-1 - ..) .. . - - - - . - 24 7 - . . . 8-800-755-2000 ( ) info 3 (057) September 2016 45 High-End testing Frame for Coiled tubings Nelson PEroZo Carlos PaZ Javier HolZMaNN Joachim oPPElt itE Clausthal university of technology . . . . () . . - . ( ). . - . . . . abStraCt Tubulars are involved in most of the activities related to the oil and gas industry. The reliability of any operation can be enhanced by predicting the lifetime of these tubulars and thus avoiding non-productive time and excessive costs. Thanks to the development of new materials and improvements of the coiled tubing technology with the years these tubulars have been lately used in more challenging operations such as drilling. With the need of accurately replicate the actual service loads acting on coiled tubings during its operation in the field a unique testing facility was designed and built to replicate all the different processes promoting the failure of these kind of pipes. The main loads acting on coiled tubings are the bending internal pressure and axial load. Unlike the rest of the tubulars used in the oil and gas industry coiled tubings work under plastic deformation because of the bending cycles encountered while passing through the reel and gooseneck. The internal pressure altogether with the alternating bending loads are responsible for the ovality of the pipe an effect representing the loss of roundness in the coiled tubing. The ovality strongly affects the capacity of the tubing to resist the presence of internal or external pressures. Since the coiled tubing is one piece of pipe which can measure even thousands of meters it is very common for this tubular to suffer elongation because of the high axial tension load represented by its own buoyed weight when it hangs in the vertical section of a well. Finally it is important to take into account the friction with the walls of the wellbore as the tubing is deployed. This friction can be represented as an induced torque in the pipe. The idea of using the coiled tubing for drilling applications makes necessary the accurate study of torsion loads in coiled tubings effect taking place due to the induced torque in the string coming from the drill bit. The new test facility is able to replicate all these possible loads either separately or at the same time by means of hydraulic cylinders acting directly on the test sample. The results of the first tests applied on coiled tubings are shown and compared with other available results. All these first tests were run with high internal pressure in order to simulate the loads acting in high pressure wells. 46 3 (057) September 2016 . . . . iNtroduCtioN With the original idea of reducing costs by testing tubulars in labs it was found necessary to design and build a new test frame where the different loads acting on the coiled tubing are replicated. Savings in time pipe material man power and safety procedures can be achieved when testing in labs where the loads can be easily controlled. Since the beginning of coiled tubing testing about 25 years ago all test facilities built only consider the application of the cyclic bending load while the pipe is internally pressurized and in few cases it was found possible the application of axial loads. The implementation of coiled tubing drilling has been continuously growing in the last years thanks to the development of new materials and technologies which make this high demanding operation possible and even standard in different places worldwide such like Alaska Canada and in the middle east. It has become really important to consider the loads acting on coiled tubings when they are used in drilling applications. The . presence of torque is imminent in this kind of operations load . that negatively affects the combined load The implementation of coiled tubing drilling resistance of the coiled has been continuously growing in the last tubing and hence the years thanks to the development of new fatigue lifetime of the . materials and technologies which make this tubular. high demanding operation possible. In this paper a 25 new test facility is presented which is able to replicate the loads necessary to accurately simulate this challenging operation which generally take coiled tubings to their load limits. This new load scenario makes obsolete the existing mathematical . prediction models for determining the fatigue lifetime of coiled tubings reason why it is necessary to establish a comparison between the test results with these existing models. The experimental results of the first tests are presented . in this document as comparison to the existing mathematical prediction models. . rEviEW oF ExiStiNg tESt FaCilitiES To start it is reviewed how the coiled tubing testing has . been performed worldwide during the last two decades. Figure 1.a shows a test facility built as an intent to standardize coiled tubing fatigue testing being designed as simple as possible with the goal to be easily available to every company and also to make the rigging of the . sample as fast as possible (Newman and Brown 1993). In this facility which is used to test pipe samples with diameters between 1 and 1 can be only applied bending cycles with internal pressure since the main target has been always focused in analyzing the main . components affecting the plasticity of the coiled tubing. The figure 1.b shows a newer test facility built to test coiled tubings with different induced surface defects 3 (057) September 2016 47 TECHNOLOGIES . . . . 1 . . (Newman Brown 1993). 31 75 44 45 . 1b . H2S (CTMRC 2016). . 1c 38 1 76 2 . (DETCRC 2016). . 1d (CTMRC 2016). . 31 75 60 33 . . . Achilles (CTES 2003) 1 Figure 1 Existing coiled tubing test facilities against bending cycles with internal pressure. This machine is also built to test new CT grades under exposure of H2S solutions. (CTMRC 2016) The machine shown in the figure 1.c was exclusively built to test pipe samples with OD between 11 2 and 3 to bending cycles with internal pressure to failure. CT samples made of carbon fibre were tested in this machine to compare their fatigue performance to the ones of normal steel pipes. (DETCRC 2016) The test facility shown in 1.d was built as part of a project called The elongation and diametral Growth JIP (CTMRC 2016) to study the coiled tubing mechanics with the idea to develop a coiled tubing plasticity model. This machine was designed to apply bending cycling and axial load to pressurized coiled tubings with outer diameters between 1 and 2 3 8 . By means of experimental coiled tubing testing it was able for different investigators to develop today s existing mathematical models to predict the fatigue life time of coiled tubings which will be shortly explained below. The mathematical models Achilles (CTES 2003) CoilLIFE and Cycle have been developed after thousands of pipes tested in labs being the most used prediction models worldwide. The Achilles model is an algorithm belonging to the Cerberus package which has been developed by Prof. Steven Tipton of the University of Tulsa (Tipton 1996 1999)). This model is based on the plasticity theory which relates the shear and the stress or strain suffered continuously updating the capacity of the coiled tubing to resist additional forces. CoilLIFE was developed for Dowell Schlumberger (CTMRC 2016) and it calculates the damage occurring during each bending cycle suffered depending on the internal pressure accumulating the total damage predicting by this way when the first crack will appear. During this investigation the strains were always measured in hoop and axial directions in order to compare the accumulated plastic deformation under different internal pressure values. In the case of the software Cycle it was developed 48 3 (057) September 2016 CoilLIFE Cycle . . Achilles Cerberus (Tipton 1996 1999). . CoilLIFE Dowell Schlumberger (CTMRC 2016). . . . Cycle 90- Nowsco Baker Hughes Inc (TCC210 2005). . . . during the 1990 s by the Nowsco and it is exclusively used by Baker Hughes Inc (TCC210 2005). All these models have in common the next input variables outer diameter wall thickness and material grade bending radii of the reel and gooseneck and the internal pressure present during the bending and straightening of the CT. Once having these variables the programs calculate the axial hoop and radial stresses after each bending event having an estimation of the incremental fatigue damage added to the CT. CoilEd tubiNg tEStiNg For drilliNg aPPliCatioNS For drilling applications the coiled tubing is subjected to axial load and torsion additional to the bending loads taking place at the well head as running through the reel and gooseneck. To accurately replicate this kind of operation the pipe samples have to be subjected to all these existing loads. The axial load is important to the applied in form of tension in order to simulate the axial load this pipe suffers as it hangs in the well during RIH or POOH and also if this is the case in compression if the CT is used directly after the BHA to simulate the WOB present during the drilling operation. Torsion loads have to be applied as well to simulate the torque induced by the drilling bit which is represented during the test as an alternating torsion oscilating between a minimum and a maximum value. This simulation is performed using a novel test facility able to apply all these possible loads on the coiled tubing samples. This machine is presented in the next section. NovEl tESt FaCility For CoilEd tubiNgS A new test facility which is able to replicate the loads involved during drilling operations especially in deep drilling must be capable to apply axial load and torque to the test sample. This new test machine can perform not only the standard bending cycles with internal pressure but also as a new test approach is presented the intervention simulation test in which the specimen is fixed at both ends with the goal of being tested against axial load and torque also in the presence of internal pressure. By this way a complete coiled tubing intervention can be reproduced beginning with the RIH replicated by bending cycles with internal pressure followed by the intervention itself which is represented by the axial load and torque also under the presence of the internal pressure and ending with the POOH which is represented once again by the bending cyles with internal pressure. All components of this new machine were designed to make the load application as similar as possible to the reality. The most critical part was to properly reproduce the bending process. In the figure 2.a is shown the arc support which replicates the path of the coiled tubing through the reel and gooseneck being this part where the bending of the pipe takes place during the test. This arc support has a curvature radius of 83 and it was built for the tests to be performed on coiled tubings having an outer diameter of 2 3 8 . In the figure 2.b is shown the straight support which is placed on the other side of the tube in order to avoid undesirable deformation . . . . . 3 (057) September 2016 49 TECHNOLOGIES . . ( ). . . . . ( ) ( ) ( ). . . 2 . . 2 1 60 33 . 2b . . 2 . . . 2d . . 2 Figure 2 components of the bending setup of the pipe such as necking as it is straightened back to its original position. Figure 2.c shows the bending mechanism which is the one transmitting the force to bend and straighten the pipe. The coiled tubing is placed between two pulleys having the form of the pipe to be tested helping to avoid unnecessary deformation of the specimen in the contact points. Finally the figure 2.d shows two plates which are placed in the middle of the frame to keep the pipe fixed avoiding any offset from its axial position. One of the plates has a rounded form to avoid stress concentrations in the specimen since this is the place where the bending process begins. In this frame axial torsion and bending loads are applied by means of hydraulic cylinders. Figure 3 shows the final test facility including these three cylinders. PrEParatioN For tHE tEStS For the first tests performed in this new facility coiled tubings with 2 3 8 of outer diameter were the biggest pipes found having a wall thickness of 0 224 and HS-80 as material grade. Before proceeding with the tests the outer diameter and wall thickness were measured in several sections of the pipes to determine their ovality and eccentricity and by this way confirm that the coiled tubings had a proper manufacturing process and are in good shape avoiding the experimental tests to deliver wrong results. Material and residual stress tests were also performed on each specimen to confirm the material had not suffered any previous deformation and that the heat treatment during their manufacture was properly performed. The material tests were done following the ASTM E8-11 (2011) and the residual stress evaluation is in accordance with the ASTM E1928-13 (2013) and CEN ISO TR 10400 2011(2011). In order to determine and control the strain during the test straingauges were positioned on the pipe samples. A maximum strain ranging in the 2% to 3% was present during the application of the bending. A total of 4 sets of strain gauges were positioned on each specimen. Three of these sets were placed in the bending section close to the area expected to failure. Each of these three sets are formed by four strain gauges located in the same transversal section and placed 90 from each other. The last set of strain gauges was placed where no bending is 50 3 (057) September 2016 . . 3 . taking place for measuring the axial strain the effect of the internal pressure and the shear strain caused by the alternating torque. ExPEriMENtal tEStS aNd rESultS In the following section of this paper the obtained experimental results are presented. 60 33 . 5 7 HS80. 3 Figure 3 The new coiled tubing test facility bending test with internal pressure . Before beginning with the new tests it was important to guarantee that the machine is delivering reliable results reason why it was started with the standard . bending test with internal pressure to validate the test . results by comparing them with the existing prediction models. For the bending tests the coiled tubing samples were subjected to 650 bar of internal pressure and they were posteriorly cycled under cyclic bending forces until failure. The tests stopped once leakage appeared and the internal pressure was lost. Figure 4 shows the . moment after one of the specimens broke. The section of maximum shear stress can be observed product of the ASTM E8-11 (2011) combined loads axial tension induced by the bending ASTM E1928-13 (2013) cycles and high internal pressure. CEN ISO TR 10400 2011(2011). In table 1 the experimental results of the first 5 bending tests with internal pressure are shown. Table 1 Bending test results . Pipe Number 1 2 3 4 5 2 3% Bending cycles to failure 55 52 49 50 50 . (4) . (3) An average of 51 cycles to failure were obtained value located between the existing mathematical models. The . existing models considered are Achilles with predicts (3) 48 cycles to failure Flexor-TU model with 52 cycles (4) and finally the Cycle model which predicts 54 cycles to failure. 90 . As shown in the figure 5 all pipes tested under bending forces with internal pressure had a similar final state . plastic deformation expected for this kind of test. In the figures 5.a and 5.b is shown the increased ovality in the pipe which for these tests was around 10%. Picture 5.c shows the pipe plastically bent. Picture 5.d shows . the ballooning effect in the pipe where the diameter increase close to the failure section can be observed. After having determined that the machine is providing reliable results the intervention simulation tests taking into account the additional loads (axial tension and torsion) were performed. . 3 (057) September 2016 51 TECHNOLOGIES . . 65 . . 4 . - . 1 (5) . 4 Figure 4 Tension and high internal pressure effect on the failure section intervention simulation test with axial load and torsion For these tests the coiled tubing samples were subjected to a critical combined load state corresponding to the 95% of their VME simulating a demanding drilling operation for the drillstring in which the presence of axial forces and torque with internal pressure are added alternated with the normal bending forces suffered while RIH and POOH. The internal pressure used for the tests was the same 650 bar used for the bending tests. The axial load was set to 240 kN in tension to simulate the tension suffered by the pipe. A cyclic torque between 2000 N-m and 3000 N-m was continuously applied to simulate the induced torque in the pipe coming from the drill bit. Figure 6 shows the location of the combined loads in the specimen s VME during the test. Rotation of the coiled tubing was not allowed in any of the tests. Before each set of bending cycles it was checked that the specimen had not suffered circumferential offset from its initial position making sure that the fibers initially located at the maximum tension and maximum compression positions staid in their places. If rotation occurred during the torsion test the specimen was always brought back to its original position. The results of these tests show a decrease of the fatigue lifetime of the coiled tubing where in average a total of 41 bending cycles were applied before failure took place. Figure 7 shows the failure section of a specimen tested under this load state. Additional deformation forms are seen having parts of the inner wall of the pipe twisted forms on the maximum shear stress plane showing how the torsion has its share in the failure of the coiled tubing. As well as for the bending tests the crack spreads from the inner wall up to the outer wall until the fracture of the specimen despite that the maximum shear stress is located at the outer walls. This means that the influence of the hoop and radial stresses are more determining in how the failure takes place. This effect can be seen in the figure 7. 1 1 55 2 52 3 49 4 50 5 50 51 . Achilles 48 Flexor-TU 52 Cycle 54 . . 5 . . 5 5b 10%. 5c . 5d . ( ). 52 3 (057) September 2016 5 Figure 5 Final state of the tested coiled tubings 95% . . 65 . 240 . 2000 3000 . 6 . . . . . 41 . 7 . . 6 Figure 6 combined loads during the tests 7 Figure 7 Final state of the cT after the test In figure 8 is shown the fatigue life of a coiled tubing affected by the torsion compared to the test results of the standard bending cycling with internal pressure for a CT with an OD of 23 8 . It can be seen in the tests performed how the torsion significantly affects the fatigue life time of the coiled tubing in around 10%. CoNCluSioNS A unique test facility was designed and built to increase the accuracy for the prediction of the fatigue lifetime of coiled tubings. The analysis of additional forces like axial load and torque acting on the specimens can provide a more realistic combined load state suffered by tubulars when subjected to different operations within the oil and gas industry. It is proven that the existing models are not appropriate to predict the fatigue lifetime of coiled tubings for demanding operations like deep drilling since it is a must to take into account the effect of the axial load and the torsion on the pipe. The fatigue life time of the coiled tubing is reduced in around 10% due to the influence of torsional forces. rECoMMENdatioNS An extensive test program can be performed in which coiled tubings of several sizes and material grades are tested to create a new algorithm based on experimental tests with the goal of creating a new mathematical model which determines with high accuracy how the fatigue life of coiled tubings is consumed under all the contemplated loads. 3 (057) September 2016 53 TECHNOLOGIES . ( ). . . . 7. 8 60 33 . 10%. 8 Figure 8 Effect of the OD on the cT fatigue life aCkNoWlEdgEMENtS This work was possible thanks to the financial support of the Ministry of Science and Culture of the state of Lower Saxony (MWK) in Germany and Baker Hughes within the research program gebo (Geothermal Energy and High Performance Drilling). . . . . - 10%. NoMENClaturE CT Coiled tubing OD Outer diameter BHA Bottom hole assembly RIH Running in hole POOH Putting out of hole WOB Weight on bit VME Von Mises envelope . . Baker Hughes GEBO ( ). REFERENCES 1. Newman K.R. Brown P.a. Schlumberger Dowell. 1993. Development of a Standard Coiled Tubing Fatigue Test. Presented at the 68th annual Technical Conference and Exhibition of the SPE. Houston Texas. USa. 3 6 October. SPE 26539. 2. Tipton Steven M. University of Tulsa. 1996. Multiaxial Plasticity and Fatigue Life Prediction in Coiled Tubing. Fatigue Lifetime Predictive Techniques 3rd Volume aSTM STP 1292 M.R. Mitchell and R.W. Landgraf Eds. american Society for Testing and Materials. USa. pp. 283 304 3. CTES L.P. achilles 4.0. CT Fatigue Life Prediction algorithm. 2003 4. Coiled Tubing Mechanics Research Consortium. 5. DETCRC Bending Machine. Deep Exploration Technologies Cooperative Research Centre. Perth australia 6. Tipton S.M. University of Tulsa. 1999. The achilles fatigue model. CTES Tech Note. 7. TCC210 Coiled Tubing equipment corresponce course. 2005. BJ EDC-Tomball Version 1.01. 8. Standard test methods for tension testing of metallic materials. aSTM E8-11. 2011. aSTM International. Pa USa. 9. Standard practice for estimating the approximate residual circumferential stress in straight thin-walled tubing. aSTM E1928-13. 2013. aSTM International. Pa USa. 10. Technical report. Equations and calculations for the properties of casing tubing drill pipe and line pipe as casing or tubing (CEN ISO TR 10400 2011). 2011. European committee for standardization. Bruxelles Belgium. 54 3 (057) September 2016 3 (057) September 2016 55 Differential sticking control methods .. . . . .. . . . .. . .. - ( ) . .. a. trEtyak doctor of Engineering Science member of russian academy of Natural Sciences y. rybalCHENko candidate of engineering sciences associate professor S. lubyaNova senior lecturer y. turuNtaEv master s degree holder Platov South-russian State Polytechnic university (NPi) . . . . . - . . . 80% 20% . . . . . The main characteristics of differential sticking are described. It is shown that most of complications are due to differential sticking. There is a detailed description of differential sticking and the ways to eliminate this effect. Drilling mud with high lubricating and anti-sticking properties is proposed at the invention level. Experimental tests proved high quality of drilling mud thus allowing to recommend its large-scale implementation in drilling operations especially for drilling directional and horizontal wells in harsh conditions. During construction of directional wells with horizontal wellbore drilling companies face almost all kinds of complications. The most frequent complication is sticking. Historically sticking effects are divided into mechanical and differential sticking. According to a modern terminology mechanical sticking can be classified under two separate categories sticking caused by drilled cuttings or cavings and jamming at intervals with a complex wellbore geometry. Differential sticking proportion is 80% proportion of mechanical sticking and sticking caused by equipment failure is 20%. Most often sticking is caused by drilling cuttings or cavings. Usually it happens during tripping up but also fixed drill string can stick when circulation is stopped for a long period. Sometimes this sticking occurs during tripping down into the well. Sticking caused by drilling cuttings or cavings is the most dangerous. Generally it is harder to release drill string which was stuck due to cuttings or cavings than drill string which was jammed at 56 3 (057) September 2016 . . . . . . . . . . . . . . . . . 50% 10%. . . . 1. - ( ). ). 2. . . Experimental tests proved high quality of drilling mud thus allowing to recommend its large-scale implementation in drilling operations especially for drilling directional and horizontal wells in harsh conditions. intervals with a complex wellbore geometry or stuck due to a differential pressure. Often most of drilling equipment is lost during recovering of stuck pipes that forces drilling company to drill a side track. The most of sticking issues caused by drilling cuttings or cavings occur during tripping up. The reason of this type of sticking is an incorrect cleanout operation or poor wellbore stability. Differential sticking is usually encountered when drill string becomes embedded in a mud cake that forms on the wall of a permeable formation during drilling. Friction between a drill string and a formation rock increases to such a high level that it becomes impossible to move drill string. This sticking occurs more often in wells that enter depleted formations. Differential sticking occurs when drill string stays immobile for a long period. Jamming at intervals with a complex wellbore geometry occurs in wellbore section where BHA (bottomhole assembly) configuration is incompatible with the wellbore shape. Sometimes BHA can t be moved through this wellbore section freely. When BHA is moved through this section under high load sticking is highly possible. In other words sticking at intervals with a complex wellbore geometry occurs during drill string tripping up and down the wellbore. Correct problem definition is the first step in the solution process. That is why the first step in stuck pipe freeing process is identifying of a sticking mechanism. After a sticking mechanism is identified freeing process can be started. It is crucial to perform initial operations quickly and correctly. The situation becomes more complex whatever the reason of sticking is. Statistically in 50% of all incidents stuck pipe is freed during the first four hours after sticking occurred whereas after four hours this factor decreases to 10%. The problem is not solved after the drill string is freed. The last step of the solution process is analysis and evaluation of performed operations in order to learn a lesson and improve the operations. After a sticking mechanism is identified stuck pipe freeing process starts with the following operations in case of sticking caused by drilling 3 (057) September 2016 57 TECHNOLOGIES . . ) ( ). 3. - . . 4. . 1. . 2. ( ). ( ). 3. . ( ). 4. ( ). 1. . . 2. . . . . . cuttings or cavings common field practices include 1. Reduction of mud-hydrostatic-pressure that was increased due to bridging of well then creation of a small pressure (too high pressure will embed BHA in a mud cake as a swab). Small pressure is required for circulation recovery in case driil string was moved. 2. Application of a torque and jarring down. If there is no jar in BHA or jar is not working - application of a torque and maximum axial stress in order to move drill string in the opposite direction to that when it became stuck. If drill string is pulled up it will become more embedded in plug. The purpose is to dislocate drill string and create circulation for plug cleanout and wash over plug material out of the wellbore. It should be noted that if drill string was tripped down when it became stuck in a deviated well then it is necessary to try to pull it up and jar up without rotation. 3. If circulation is recovered it is necessary to increase rate to the maximum possible value without circulation loss. Then circulation should be resumed until the well is cleaned out. 4. It is necessary to ream the interval and trip BHA back to the bottomhole before running the casing or other well tools. in case of differential sticking it is necessary to 1. Immediately apply a maximum torque and bring it to sticking zone. 2. Resume circulation with maximum accepted rate (simultaneously with torque application). If there is a jar tool in BHA it is necessary to reduce pump rate to the minimum value when jarring down in order not to resist jarring. 3. Quickly slack off drill string with maximum axial load while keeping applying a torque. It is strictly prohibited to pull drill string up (This will lead to a sticking complication drill string straining will reduce torque that can be safely applied to a drill string). 4. In case there is a jar in BHA it is necessary to jar down (don t forget to reduce pump rate to a minimum value in order not to resist jarring). in case of jamming at interval with a complex wellbore geometry it is necessary to 1. Jar down in the opposite direction to that when drill string became stuck. Apply a torque when jarring down but no torque should be applied when jarring up. 2. It is necessary to monitor circulating mud pressure during the loading phase and jarring. Increase in this pressure leads to increase in jar up force and decrease in jar down force. This pressure impedes the loading phase for jarring up and helps deliver a compressive force for jarring downward. There are several factors assisting differential 58 3 (057) September 2016 . . . . . . . . . . . . . . . . . . . . F P S F P S 2. . . . sticking permeable formations overbalance pressure thick mud cake contact of drill string and wellbore wall stationary drill string time lateral load driller s poor attention. Usually differential sticking occurs when the first six factors are encountered. If there are only five of them sticking is unlikely. The seventh factor lateral load is not necessarily needed for sticking but this load assists it. All these factors influence differential pressure force that makes drill string stick to wellbore wall with a mud cake. The following specifies all these factors in more detail. Differential sticking can only occur in permeable formation interval. Sticking inside the casing is impossible except for those cases when fluid channels develop in casing for example perforation holes or casing leakages due to wear. Permeable formations can be composed of sandstones and fractured rock. Sticking is also possible in permeable and fractured clay rock intervals. Sometimes sticking is encountered in casing perforation interval or leakages zones that developed due to internal wear. If there is no permeable formation this means that there won t be a filter mud cake or differential pressure. Differential sticking occurs not only in highlypermeable formations. The formation must be permeable enough for the development of filter mud cake. Filter mud cake is the residue deposited on a permeable medium. Drilling fluid filtrate passes through this mud cake. That is why formation permeability must provide filtrate outflow away from the mud cake. Thus more attention should be paid to mud cake permeability rather than formation permeability. Usually permeability of unconsolidated formations is higher and mud cake that develops on a medium is more permeable in comparison with that in consolidated formations. The higher the permeability the more probable differential sticking is. However permeability assists differential sticking to a lesser extent than other factors. Overbalance pressure is the main factor that assists differential sticking. This is due to the fact that in comparison with other factors overbalance pressure affects the force that makes drill string stick to a wellbore wall with a mud cake to the maximum extent. This force is equal to the product of differential pressure and area of contact Fst Pdif S where Fst - sticking force N Pdif - differential pressure Pa S - area of contact m2. It is evident that higher differential pressure creates higher sticking force. It should be noted that differential pressure that makes drill string stick to a wellbore wall with a mud cake is not equal to overbalance pressure. Overbalance pressure means that well pressure is greater than formation 3 (057) September 2016 59 TECHNOLOGIES . ( ) . . 1. () . ( ..) . . (10 15%) ( 0 8%) - [1]. () . . Wellbore Permeable filtration mud cake Permeable formation Drill string Drilling mud pressure Formation pressure 1 Figure 1 Differential sticking mechanism during drilling pressure. Differential pressure is a pressure difference between two sides of any surface. Differential sticking occurs in permeable formations intervals (sandstones siltstones limestones) during drilling mud filtration. Sticking mechanism during drilling is presented on a fig. 1. One of the main sticking conditions bottomhole (hydrostatic) pressure is greater than permeable formation pressure which always exists. The second essential condition is a stationary state of BHA (during adding of drill pipe and so on) in formation interval. In these conditions differential sticking can occur within several minutes depending on filtration rate. Differential sticking is an emergency situation during drilling. That is why there are many instructions for prevention and mitigation of sticking. These instructions include the following actions Using high-quality and high-lubricity drilling muds that develop a solid mud cake on a wellbore wall Providing maximum possible velocity of the upward drilling mud flow. Providing full drilling mud cleanout from drilling cuttings Regular reaming of thick mud cake intervals during drilling Increasing mud weight during drill string rotation Monitoring of mud temperature since a sharp decrease in temperature indicates that drilling string thread joints above a bit are washed out Using preventive additives to heavy drilling muds oil (10 15%) graphite (not more than 0 8%) surfactants. Installation of hydraulic and mechanical jars Performing liquid treatments based on salts acids and hydrocarbons [1]. Operation principle of freeing stuck pipe after differential sticking is the reduction of pressure 60 3 (057) September 2016 . - . () - . . () . - . -11 . % 5 10 2 10 2 5 2 5 1 4 1 5 4 2 5 1 5 -11 2 5 0 5 5 0 5 1 . % 55 45 80 20. - . . . difference on wellbore wall in the formation direction. This reduction is achieved by the loosening of mud cake in sticking zone. The most effective method is providing filtration of antisticking fluid through the fractured mud cake. Fracturing makes the mud cake permeable for hydrocarbons due to forming of large-diameter channels and increase in filtration rate in sticking zone. Hydrocarbon fluid filtrates through formed channels from well to formation pores and decreases pressure difference in well-formation system. This leads to freeing of stuck pipe. Special surfactants are required for speeding up fracturing and fluid filtration processes. These surfactants assist filtration of hydrocarbons through mud cake. In-depth study of drilling technology geological complications and accidents at Yamburg gas condensate field suggests that drilling mud applied for well cleanout does not perfectly meet high standards for drilling sticky clay rocks especially in directional and horizontal wells. As a result a low-quality clay polymer mud cake forms along a wellbore wall. This mud cake exhibits low filtrating and inhibiting properties that is the main reason for differential sticking. Team of Oil and gas equipment and technologies department in South-Russian State Polytechnic University (NPI) developed a complex multi-agent high-molecular inhibiting drilling mud with high lubricating filtrating consolidating and rheological properties. This drilling mud is designed for drilling oil and gas directional and horizontal wells in rocks composed of thick sticky clays that may swell and break up thus causing wellbore stability problems. The assigned task is solved by adding several components to a drilling mud. Drilling mud includes polyanionic cellulose potassium chloride barium sulphate bischofite ferrochromelignosulfonate potassium methylsiliconate potassium acetate antifoaming agent and water. Additives include marble aggregates vegetable oil wastes natural gas liquid NGL-11 sulfanol. Components proportion is as follows % wt marble aggregates 5 10 polyanionic cellulose 2 10 sulfanol 2 5 potassium chloride 2 5 potassium methylsiliconate 1 4 potassium acetate 1.5 4 bischofite 2 5 ferrochromelignosulfonate 1 5 NGL-11 2 5 barium sulphate 0.5 5 antifoaming agent 0.5 1 liquid phase the rest. Liquid phase includes vegetable oil wastes and water in proportion % wt 55 45 80 20. The technical result of this mud is the improvement of lubricating consolidating and antisticking properties of the inhibitor-based drilling mud with simultaneous improvement of coefficient of initial permeability recovery by enhancing inhibiting and water-repellent abilities of mud filtrate. As a result there are no key seating and 3 (057) September 2016 61 TECHNOLOGIES . (KCl) (MgCl 62O) (3) (-11) () (CH3SiO2K). - . 1 -11 . . . . ( 85 700) . - 465 . 0 5% 10%. [2 3 4]. . . 1. . . . . KCl CH3COOK CH3SiO2K MgCl 6H2O -11 . . 4- . . - differential sticking problems as well as wellbore stability is enhanced in directional and vertical wells. At present time the application for a patent for the invention of drilling mud composition is filed. Inhibiting properties improvement is achieved by enhancement of consolidating ability. Laboratory tests proved synergistic effect of each component. It is achieved by adding the following agents - clay swelling inhibitors potassium chloride (KCl) bischofite (MgCl 62O) potassium acetate (3) organosilicon fluids (NGL-11) ferrochromelignosulfonate (FCrLS) potassium methylsiliconate (CH3SiO2K). Combination of these six main inhibiting agents is the most efficient for drilling wells in harsh conditions. The team identified how plastic viscosity yield point and mud filtration depends on concentration of inhibiting agents KCl bischofite potassium acetate NGL-11 potassium methylsiliconate FCrLS. Wastes obtained during manufacturing of soya-bean sun flower cottonseed corn rubsen and other oils can be used as vegetable oils. Sulfanol acts as an emulsifier which is a synthetic anionic surfactant in the form of powder which is very soluble in water and creates stable emulsion. Marble aggregates act as a gelling agent. Polyanionic cellulose (PAC 85 700) serves as a filtration controller. Penta-465 is a widespread antifoaming agent. Barium sulphate as a mud weighting agent is used in the ratio of 0.5 10%. Rheological properties of the mud assist in enhancing wellbore stability and effective well cleanout operation [2 3 4]. Authors proposed a complex multi-agent high-molecular inhibiting drilling mud with high lubricating filtrating consolidating and rheological properties. Laboratory tests results are presented in Table 1. The proposed drilling mud is prepared in the field using available equipment. All required chemical agents are delivered to the drilling rig in advance. In the first place marble aggregates and water are used for preparation of a mud which is then treated with polyanionic cellulose. All other agents are added into mortar-mixing machine with constant mixing. The adding order of chemical agents is as follows vegetable oil waste KCl FCrLS CH3COOK CH3SiO2K MgCl 6H2O sulfanol NGL-11 antifoaming agent barium sulfate. Rheological properties of drilling mud are determined by standard methods. It is recommended to treat drilling mud with chemical agents after 4-stage purification. High-pressure dispersing agent is used for mud preparation. Inhibiting mechanism is as follows adding inhibiting agents in drilling mud leads to a chemical reaction of clay and cation that replaces free anionic parts of crystal lattice of clay particles. 62 3 (057) September 2016 . . . 0 3 30 . ( 85 700). . - . . . . . . pH- - . . .. . During cationic exchange inactive clay parts become active. Adsorption of inhibiting agent on clay particles enhances clay water-repellent ability and prevents clay from swelling and break-up. One of the main conditions of wellbore stability control is providing minimum possible filtration factor up to 0 sm3 30 min. This is accomplished by means of polyanionic cellulose (PAC 85 700). It is found that the main factor in clay breakup is not an initial clay moisture it is a mud filtrate saturation under the effect of overbalance pressure. Mud filtrate loss occurs not due to the difference in pressure in well-formation system. This is due to physical-chemical reaction inside the clay rock. The ideal case for maintaining wellbore stability is when osmotic equilibrium is established in well-formation system or osmosis is directed from the formation to the well. In this case drilling mud properties are affected by osmosis direction but it is easier to manage these properties and maintain them within the assigned limits rather than mitigating complications after wellbore collapse. Consequently clay stability will depend on the correctly selected chemical agents and in the first place it will depend on the inhibiting agent. This is the high-priority task that needs to be solved. Application of the proposed drilling mud makes possible drilling rock intervals composed of unstable highly-plastic clays and drilling vertical directional and horizontal wells. The above mentioned inhibiting agents enable performing and controlling coagulation process maintaining pH-value within the required limits managing rheological filtration properties and the optimum liophilic behavior. The technical result is the improvement of lubricating consolidating and anti-sticking properties of the hydrocarbonbased drilling mud with simultaneous improvement of coefficient of initial permeability recovery by enhancing inhibiting and waterrepellent abilities of mud filtrate. As a result there is no key seating in the wellbore. Laboratory researches established that the application of six clay swelling inhibitors simultaneously in one drilling mud leads to a synergistic effect inhibiting ability of the drilling mud is enhanced. Each component complements one another and enhances consolidating ability of the drilling mud. In addition combination of chemical agents in this composition displaces sodium cations from clay formations and sodiumionized clay becomes calcium clay. This prevents clay from hydration and swelling reduces clay warping and flowage and prevents rock cavings. The advantage of the developed mud is that during reaction between the mud and the clay under study concentration of ions increases from 800 to 1299 mg l. This shows that the osmotic process is directed from the formation to 3 (057) September 2016 63 TECHNOLOGIES 1 Table 1 Drilling mud Chemical agents composition Marble aggregates 85 700 PAC 85 700 KCl FCrLS CH3SiO2K CH3COOK MgCl 6H2O Sulfanol -11 NGL-11 Antifoaming agent Barium sulphate Liquid phase the rest oil water 3 () Density g cm3 (areometer) Mud parameters (-5) Viscosity s (March funnel) 3 30 (-6) Water loss cm3 30 min (-2) Friction coefficient 30 32 33 34 35 36 37 40 Mud 1 5 0 5 0 2 0 1 0 1 0 1 5 2 0 2 0 2 0 0 5 0 5 Mud 2 6 0 6 0 2 0 1 5 2 0 1 5 2 0 2 0 2 5 0 5 1 Mud 3 6 0 6 5 2 0 2 0 2 0 1 5 2 5 2 5 3 0 0 5 1 Mud 4 7 0 7 0 3 0 2 5 2 5 2 0 2 0 3 0 3 5 1 2 Mud 5 8 0 7 0 3 5 3 0 3 0 2 5 3 5 3 0 3 5 1 2 Mud 6 9 0 8 0 4 0 4 0 3 5 3 0 4 0 4 5 4 0 1 3 Mud 7 9 0 9 0 4 5 4 5 3 5 3 0 4 0 4 5 4 0 1 4 Mud 8 10 10 5 5 4 4 5 5 5 1 5 55 45 60 40 65 35 65 35 70 30 75 25 75 25 80 20 1 16 1 18 1 19 1 20 1 20 1 21 1 21 1 22 3 5 2 5 1 5 1 5 1 5 1 0 0 5 0 0 15 0 14 0 17 0 12 0 12 0 08 0 09 0 06 . 800 1200 . K icp 1 31. 4 7. . 3000 . 8 1 22 3 the well while isotonic coefficient is not high K iav 1.31. The presence of potassium and magnesium ions in the mud makes isotonic coefficient increase significantly up to 4.7. Thus the number of osmotically active particles increases due to the electrolyte dissociation. The application of this mud will make possible to drill wells with depth up to 3000 m at the rock intervals composed of unstable highly-plastic clay formations. The optimum drilling mud 8 will have the following properties density 1.22 g cm3 viscosity 40 sP water loss 0 cm3 per 30 min friction coefficient 0.06 (table 1). The proposed mud exhibits high inhibiting properties and zero filtration as well as improved rheological anti-sticking and ecological behavior for drilling in harsh conditions. Experiments in laboratory (table 1) proved the synergistic effect of a complex treatment of the drilling mud with several inhibiting agents. 64 3 (057) September 2016 40 0 3 30 0 06 (. 1). - . (. 1) . 80 . 0 3 30 0 0 1 0 5 % 55 45 80 20 1 1 1 2 3 -5 35 40 20 40 1 10 15 20 20 30 0 5% 16 000 Cl 30 000 . 3000 . . Mixing of components in the optimum proportion enhances the efficiency of inhibiting filtrating lubricating anti-sticking and antiwear properties of separate components in the proposed mud. These properties do not change at temperature up to 80 . The parameters of the proposed hydrocarbonbased drilling mud with high inhibiting filtrating and lubricating properties are as follows mud filtration 0 cm3 per 30 min mud cake adhesion factor 0 friction coefficient is lower than 0.1 mud cake thickness is lower than 0 5 mm oil water ratio from 55 45 to 80 20 % mud density from 1.1 to 1.2 g cm3 Marsh funnel viscosity 35 40 s plastic viscosity 20 40 mPas static shear stress 1 10 min 15 20 20 30 dPa sand content is lower than 0 5% content is higher than 16 000 mg l Cl content is higher than 30 000 mg l. During research it was concluded that the application of this mud will make possible to drill wildcat oil and gas wells with horizontal sections at depth up to 3000 m in the rock intervals composed of unstable highly-plastic clay formations and self-dispersing shales experiments proved the synergistic effect of drilling mud components combination of several agents works better than each component separately new mud composition exhibits the highest inhibiting ability thus preventing clays from hydration and swelling the proposed combination of agents prevents and diminishes deformation processes in the immediate vicinity of the wellbore and reduces cavern porosity the proposed drilling mud exhibits higher lubricating and anti-sticking properties with high energy-efficiency factor and environmental compatibility of all additives. The mud reduces the risk of differential sticking improves rheological mud velocity profile in annulus and enhances emulsion stability. All this assists the effective execution of well cleanout program. REFERENCES 1. .. .. .. . 2008. 424 . 2. .. .. .. () . .. . 2014. 374 . 3. .. .. .. .. . 2011. 2 3 (36). . 13 20. 4. .. . -. 2000. 139 . 3 (057) September 2016 65 TECHNOLOGIES - .. . . . . ( ). . 15 20 . . . ( . 1). . - - . 1- 3000 () [1 2] () 1 2 3 . 2- 3500 [1] . 3- 3500 4000 - ( ) - - - . 1 3- 1) ( . . .. ). . 1974. 2) .. .. . 2000. 66 3 (057) September 2016 3 (057) September 2016 67 SpE IcoTA 2016 SpE IcoTA coiled Tubing & well Intervention conference & Exhibition 2016 Abstracts . . . 22 23 2016 . - (SPE) (ICoTA). 2016 . . . SPE ICoTA 2016 . ( ) (BHP Billiton) . The Coiled Tubing & Well Intervention Conference & Exhibition took place at the George R. Brown Convention Center in Houston Texas USA on March 22 23 2016. The annual event was organized by the Society of Petroleum Engineers (SPE) and the Intervention & Coiled Tubing Association (ICoTA). The 2016 event covered innovative solutions case histories and performance improvements across all sectors of well intervention including Coiled tubing Wireline and tractor Hydraulic workover snubbing Pumping services General themes that were covered included technology and applications offshore as well as onshore operations and HSE. In the light of current industry challenges a special focus was made on increasing operations efficiency reducing non-productive time and cost effective well abandonment. Coiled Tubing Times presents the abstracts of the most interesting reports made during the SPE ICoTA Coiled Tubing & Well Intervention Conference 2016. improved Ct Well Cleanout and Milling Procedures utilizing only Nonviscous Cleanout Fluids Valeriano CANO Walther Garcia CARDONA and Marcio de ARAuJO (Schlumberger) Christopher MuRPHy (BHP Billiton) The use of coiled tubing service in the shale market has been of great importance in the process of preparing O&G wells for production mainly in the post-fracturing isolation plug milling and solids cleanout. 68 3 (057) September 2016 . () . . . - . . ( ). . . . . (Athena Engineering Services) . (Blue Ocean Technologies) . ( ) . . ( ). . . . The challenges that the coiled tubing (CT) industry has been facing are substantial and range from CT pipe manufacturing and related technical matter to logistic and operational conditions. The CT industry has worked relentlessly to remain competitive both in efficiency and economic terms in comparison with new competitive completion techniques. Well cleanouts are by far the most common operation performed with coiled tubing on a worldwide basis and also one of the most complex operations due to the large amount of operational variables involved. The shale market experiences the very same scenario and cleanout-milling activity is far from flawless. Substantial amounts of solids mainly the heavier ones remain in the wellbore after the cleanout operation is completed. Some of the traditional and deeply rooted techniques utilized in well cleaning nowadays have their origins in drilling and work-over operations in vertical wells. Some new important techniques presented in this paper primarily addressing operations in horizontal shale wells helped to improve overall efficiency during cleaning-milling operations. defining operational limits of a riser-less Ct intervention System P. KEllEHER and K. NEWMAN (Athena Engineering Services) N. CRAWFORD (Blue Ocean Technologies) The concept of riser-less coiled tubing (CT) interventions in offshore wells promises significant reductions in both cost and non-productive time associated with many offshore well interventions. However conveying CT from a vessel through the open ocean into a high pressure subsea wellhead without a marine riser package poses several significant technical issues that must be identified and mitigated in system design and pre-job planning. Some of these issues include High stress to yield ratios in heavy seas. Catastrophic buckling in the water column. Synchronization of tubing payout and wellhead entry rates. Subsea wellhead snubbing at high differential pressures. This paper will present the overall system design of a riser-less offshore coiled tubing intervention system (slated for full scale testing in late 2016) engineering principles utilized for analysis and will present an 3 (057) September 2016 69 TECHNOLOGIES ( 2016 ) . . . . - . (National Oilwell Varco) . . (Halliburton) () ( ). 896 . ( ). NACE TM0177 Method B ( ) . pH 2 8 5 5 H2S 0 5 1 . . . . Hydrajet- (Halliburton) () . . ( ) example riser-less CT operational envelope based on CT forces and stress limits. Also discussed is a set of tests performed to validate the forces model. High-Strength Coiled tubing can be used Successfully in Sour Environments if Properly Managed T. GRAHAM-WRIGHT and K. EllIOTT (National Oilwell Varco) R. SPOERING and R. HAMPSON (Halliburton) High-strength coiled tubing (CT) was subjected to sulfide stress cracking (SSC) testing for the purpose of defining acceptable operating zones in sour environments both with and without inhibition. In this case 130 ksi specified minimum yield strength tubing was used. This paper presents a summary of the results with conclusions lesson learned and recommendations for sour zones of high-strength CT with and without inhibition. Coupons of CT were tested in accordance with NACE TM0177 Method B (four-point bent beams) to determine if cracking occurred in different sour environments. Sour environments were tested ranging from in-situ pH of 2.8 to 5.5 and H2S partial pressure of 0.005 to 10 bar. Testing was performed both including and excluding chemical inhibition. Coupons tested were removed from as-milled tubing and tubing that had been subjected to low-cycle plastic fatigue under pressure on a laboratory CT fatigue testing machine. Plasma arc bias welds high frequency induction seam welds and parent material coupons were tested. Novel abrasive Perforating with acid Soluble Material and Subsequent Hydrajet assisted Stimulation Provides outstanding results in Carbonate gas Well Alejandro CHACON Jose Camilo Jimenez FADul and Jose NOGuERA (Halliburton) Abrasive perforating with coiled tubing (CT) has been an industry available technique for several decades now and has proven to be a valuable alternative to conventional perforating with electric line (e-line). The application is even more valuable whenever a high rate or fracture stimulation treatment is to follow because of the significant reduction in tortuosity and pumping friction losses across perforations. One of the primary drawbacks of this 70 3 (057) September 2016 . . . Hydrajet. . Hydrajet . plug-and-perf- . . (Baker Hughes) (Island Offshore) - RogFast . . . . . . . type of perforations is that it is a much lengthier process compared to conventional perforating and it requires large amounts of fluids and additional CT runs in the well to complete. These drawbacks discourage the wide use of the technique for more conventional applications. This paper discusses a novel approach to abrasive perforating with the first ever use of an acid soluble abrasive material ending with a hydrajet assisted nitrified stimulation. The primary advantage of this abrasive material is that there is no need for additional cleanout runs and changeover of tools thus significantly reducing operational time and fluid volume. Just as well the benefits of combining the enhanced connectivity to the reservoir and the hydrajet assisted stimulation were reflected in outstanding gas production results which exceeded all expectations. And finally as an added benefit given the nature of the focused stimulation this type of treatment in specific cases can replace plug-and-perf (P&P) or multistage fracturing completions thus eliminating operational risks and added completion costs. Successful Core drilling Project using Coiled tubing From a riserless light Well intervention vessel in a Norwegian Fjord Susana ROJAS and Michael TAGGART (Baker Hughes) Per BuSET (Island Offshore) This paper details the planning design and execution of a successful project involving the core drilling of three wellbores using coiled tubing directional drilling along the future RogFast tunnel route on the Norwegian coast. The project obtained core samples to verify rock quality prior to the commencement of tunnel drilling. The project required several new technologies and techniques to enable the collection of the core samples. The combined use of surface and subsea coiled tubing injectors operated from a vessel in combination had not been attempted and therefore was an area of concern which was addressed during the operation design phase. Project planning included the theoretical analysis of the fatigue effects on the coiled tubing between the surface and the subsea injectors requiring the development of a secondary injector control panel and several modifications to the vessel systems. The project resulted in a successful drilling and coring operation without incident or environmental spill following many months 3 (057) September 2016 71 TECHNOLOGIES . . .. (BP Norge) . . . (Qinterra Technologies) . (Altus Intervention) Valhall 241 (7) . . . 19 88 . - . . . . (152 ). . . (Total E&P Indonesie) (Welltec) . . . . of planning job design and use of a highly skilled team during the operation. removing Settled barites From a Wellbore using an Electrically Powered Well Cleanout System T. KlEPPAN and K. O. DAHlE (BP Norge) B. TINNEN M. BRANKOVIC and l. OSuGO (Qinterra Technologies) R. DANIElSEN (Altus Intervention) This paper describes a job on a well in the Valhall field to remove approximately 241 liters of settled barite in order to gain access to retrieve a bridge plug assembly that had been installed in the well for more than seven years. The traditional industry methods of cleaning out such debris are mechanical bailers run on slickline or coiled tubing. The clean out was initially started as planned with conventional bailers run on slickline. After 19 runs and 88 liters of debris removed mechanical slickline bailers made no further progress as a result of increased debris compaction. The powered wellbore cleanout system was then run. This system had been extensively tested on a test rig before the job with samples simulating expected downhole debris conditions. This testing resulted in a number of toolstring configuration options dedicated to the downhole challenges expected in the well and the use of two technologies (debris collector and suction tool) to retain and transport the debris from the well. The powered wellbore cleanout system successfully removed all the remaining debris (152 liters). It was able to continue from where the mechanical slickline bailers stopped and removed the remaining debris three times faster than the mechanical slickline bailers. Each run with a powered wellbore cleanout system could collect on average approximately five times the volume of debris collected by conventional slickline bailers. downhole Machining with Electric Wireline technology Irwan BERMAWAN Indah PRIMASARI Risal RAHMAN and Ramadhani RACHMAN (Total E&P Indonesie) Vera CAROlINA and Rigel AlDEBAREN (Welltec) This paper will demonstrate technology to do downhole interior reconstruction in an older well design to create larger tool access using wireline technology. The intent is to 72 3 (057) September 2016 . . . (E Plug) (Statoil) . . . . . . . . . document the applied technology and the value creation. The methods described were actual field operations demonstrating the successful application of the technology in a mature field. This paper will describe the history background and challenges of a well in this mature field and the subsequent application of alternate technology to overcome those challenges and maintain the asset as a viable producing well. Due to the availability of downhole tools and services to solve an immediate problem in a well the need to reconstruct the existing wellbore interior to create larger access for example becomes inevitable in many cases. Such was the case on offshore wells in Indonesia where the inner diameter size of the downhole accessories forbids tools to reach the lower targeted depth. First use of Multiple Set and release barrier Plug technology on E-line Hein Andre lANGAKER and Thomas Bergan JOHANSEN (E Plug) Sveinung ROBERTSEN and Per Kristian SKRETTING (Statoil) Wells that produce hydrocabons or provide injection into the reservoir may have a long life span and often require intervention by wireline or coil tubing in order to optimize the production rates and oil water gas ratio. Scenarios where the casing tubing is deformed or contains depositions of materials like for example scale or sand provides a challenging environment for conventional plugs to seal and hold pressure. This paper will provide insight into the field trial and development of a single run multiple set barrier plug technology that was designed to mitigate the risks associated with conventional plug operations. The plug and electric manipulation tool (EMT) was run on wireline in a deviated production well with gas lift and set at three different depths to verify the location of a leak and elimate that the leak was in the one of the side pocket mandrels (SPM). All of the operational features of the technology was tested on this one run including the selective equalization method and the ability to latch on and off with the running tool. In its first use the technology successfully verified that the leak was not in the SPMs and provided reliable data that shows that the ability to set and reposition a barrier multiple time can be useful in many applications as it improves operational efficiency and safety while at the same time reducing risk. 3 (057) September 2016 73 TECHNOLOGIES Coiled tubing technologies are demanded in oilfields of vankor Cluster and across East Siberia .. 1970 . . 1996 . 1996 2000 . 2000 2002 - . 2002 2004 ( -) ( ). 2004 2011 ( ) . 2011 - . . NOVICHKOV was born in 1970 in the town of leninogorsk Tatarstan. He graduated from Tomsk Polytechnic university with a degree in Geology and Exploration of Oil and Gas Fields. He also graduated from yugra State university with a degree in Economy and Management at the Companies for the use of Natural Resources. . Novichkov has been working in oil and gas sector since 1996. 1996 2000 JV yugraneft Corporation Well Surveying Operator Foreman of Well Surveying Team Geologist. 2000 2002 -- OJSC Slavneft-Megionneftegaz Senior Geologist of EOR Department. 2002 2004 OJSC yugraneft Corporation(the company became a part of TNK-BP) Deputy Chief of Geologocal Service (Deputy Chief Geologist). 2004 2011 llC Newco Well Service (Trican well Service) consequentially worked in the following positions Deputy Chief of Geological Service Deputy Chief for Production of Nefteyugansk site Chief of Vankor site. Since 2011 has been working as a Director of Krasnoyarsk branch of BVT-Vostok that has its main operations at Vankor field. 74 3 (057) September 2016 .. - . 2015 - intervention technology award (iCota ). - . . . . .. . . . . . .. . - .. . . 2015 . . Our company has all needed for effective realization of its projects and assigned tasks. Coiled Tubing Times Journal held an interview with the director of the Krasnoyarsk branch of BVT-Vostok A. Novichkov. bvt-vostok company was pronounced the winner of intervention technology award 2015 in the category breakthrough of the year the fastest-growing company . the award was established by the russian Chapter of the invention and Coiled tubing association (iCota). 3 (057) September 2016 75 PRACTICE . . .. . . . . . . . . The main area that causes difficulty is precisely the horizontal wells.The next area is multilateral wells that demand individual decisions. Coiled tubing times Mr. Novichkov how has the strategy and tactics of the krasnoyarsk branch of bvt-vostok changed recently due to not very favorable economic conditions alexander Novichkov There are no principal changes for our company. That is because we managed to tool up and reach a high technical level on time before sector sanctionshave been imposed and petroleum price has fallen. As a result the letter factor may only have an indirect influence on our activity. Our company has all needed for effective realization of its projects and assigned tasks. .. ... 44 . . Ctt Has the scope of works changed Many companies representatives admit that cheaper and fast-payback projects are more commercially successful. Has such a correction been made in your company a.N. No to this extent we have no significant changes. The scope of works in Vankor Field where we have been rendering a service for 4.5 years stayed the same. What concerns our other projects like in the Tyumen Region there are signed contracts which determine what work activities should be done. We launch both easy and cheap operations as well as interesting ones that have never been conducted in these areas before. 76 3 (057) September 2016 . . .. . .. 30 20. . . .. . . Ctt the percentage of such operations hasn t decreased compared to overall volume has it a.N. No it hasn t. Ctt Name the main types of operations in which krasnoyarsk branch of bvt-vostok is specialized. a.N. Works related to geophysics account for 40%. Then we should mention different types of well cleanout bottom-hole zone treatment of production and injection wells with complex acid compositions. Manymillingshave been conducted esp. in year 2015. Nowadays we also work on gas-condensate wells in Yamal. Ctt your company and you personally have gained extensive experience in the area of coiled tubing technologies. From your point of view have they evolved and are they evolving in russia a.N. Yes I can definitely assume that an evolution is occurring to coiled tubing technologies. Its strategy is the following operations complexify. Well profiles are becoming more and more difficult many horizontal wells appear. They generally take the area of 1 kilometer or more. That means the technology of delivering tools into the well or mounting certain kinds of operations in such wells should also be changed. Taking all these obstacles into consideration coiled tubing is evolving. Ctt in what extent is the size of the tube becoming luger a.N. Not only the size... We mainly work with 44 mm tubing size. Coiled tubing itself is modernized in accordance to the information on new profiles of different wells. As a rule we take the most difficult well and knowing its characteristics we project our equipment. The main area that causes difficulty is precisely the horizontal wells.The next area is multilateral wells that demand individual decisions(i.e. special tools etc.) Easy operations like well cleanout and millings are not subjected to considerable changes. Ctt What brand of coiled tubing units does your company use a.N. We currently have 3 units produced by FIDMASH (Model MK30 and MK20). We also have one unit of foreign production. Ctt How has the equipment proved itself in exploitation a.N. At first similar to using any complicated technics some problems occurred the units were working in. At present time everything works safe and sound. Ctt does your company plan to expand its equipment stock a.N. Yes sure. We are currently forming a fully featured fleet centered around recently acquired unit . oiled tubing technologies are highly demanded in east Siberia because in this region wells have difficult profiles. .. . . . .. . -- - . . 3 (057) September 2016 77 PRACTICE .. . . . . .. . . . . - 2016 22 . . .. . . . .. .. . . . . . . .. . . - . produced by FIDMASH. That is our 4th one. Ctt How can you estimate the results of imports phase-out policy actively conducted in russia a.N. That s a very sore subject for our sector. Everyone is talking about imports phase-out but in fact when we reach native producers they generally tell us We don t have any interest in making one or two or ten items for you. We can make an assembly line and give you a jillion of them . Ctt that means there isn t any flexibility is there a.N. They are absolutely inflexible. The only company that saves the day is SVMZ. This is a mechanic plant a part of a larger company BWT. We order most of shore tracks there. Ctt What can you say about east Siberian coiled tubing perspectives a.N. Nowadays coiled tubing technologies are highly demanded in east Siberia because in this region wells have difficult profiles. Rosneft intensively develops Vankor cluster including Vankor Susun and Tagul oilfields. The company also plans to develop Lodochnoe oilfield of the same cluster in the future. Practically all the wells there need coiled tubing. Without it there will be a difficulty in realization of the complicated geological and technical activities. Ctt From the rosneft senior vice-president Eric liron s point of view oil extraction in vancor cluster in 2016 will account for 22 million tons . there is no doubt that such a result can also be reached by coiled tubing technologies. and where do things stand in terms of hydraulic fracturing in vankor a.N. Hydraulic fracturing in Vankor hasn t shown expected results. That happened obviously due to geological reasons. Hydraulic fracturing technologies might be successfully realized in the adjoining oilfields of the cluster. In Vankor itself large work on support of oil extraction has been realized well maintaining stimulation of oil recovery etc. activities are conducted. 78 3 (057) September 2016 . . It is very desirable that the companies would share the information. We should provide the consistency of operations to do a good impression on the employer and show him that we are professionals. That will help a new company to work for the employer as effectively as the previous one did. . - . . . . . . . . 17- . .. . . . Ctt do you find Coiled tubing times journal useful in your work a.N. I find it extremely useful. We have only one specialized periodical in the country. We would like to receive as much information about innovative technologies and equipment as possible. I mean technologically new equipment. Such information helps a lot in our work. Ctt We will try to devote more attention to these aspects. do you have any requests on materials for hi-tech petroleum service specialists a.N. I would like all of us this sector s professionals to lead a more active conversation. We all go around the same circle so to say. One company leaves an object the other goes there. That happens according to inner tenders and signed contracts. It is very desirable that the companies would share the information. Moreover there can t be any top-secrets. The specialists are interested in technical and not in commercial part.The employer generally doesn t want to solve these questions he is concerned only about the result. In this situation we the oilfield services companies need to cooperate. We should provide the consistency of operations to do a good impression on the employer and show him that we are professionals. That will help a new company to work for the employer as effectively as the previous one did. That way we could always keep our service at the acceptable level. That would be great I wish a number of companies stopped being modest and shared some information. We try to give an example. When other companies refer to us we don t hesitate to give useful advice. Why reinvent the wheel and make others do it Ctt Maybe the 17th meeting of our annual international Scientific and Practical Coiled tubing Hydraulic Fracturing and Well invention Conference taking place in November may help to establish communication that is more effective. a.N. The communication at the conference cannot be overestimated but I was speaking about questions that are more specific. An engineer wants to get actual information from his colleague in another company that has already worked in the oilfield. Ctt you have raised a very important topic. let us hope that this interview will help to establish such communication between specialists. We wish good luck to your company interviewer Halina bulyka Coiled tubing times 3 (057) September 2016 79 PRACTICE THE FUTUrE BELONGS TO HIGH-TECH COILED TUBING SErVICES .. 17.01.1984 . 2006 . 2006 - ( -- ) . 2010 -- . 2015 -- -- . 2016 -- . Danila GAIDARJI was born in Gubakha town in Perm region on January 17 1984. In 2006 he graduated from Perm Technical university majored in Oil and Gas Geology. He started his career in 2006 at ural-Design-KRS llC (subsidiary of ural-DesignPNP llC) as a geologist in well workover department. In 2010 he was promoted to the post of chief geologist in ural-Design-KRS llC. After creating managing company ural-Design-Group llC in 2015 he advanced to the position of director of innovation and design development department in the abovementioned company. In 2016 he was appointed to the position of Chief Operations Director Deputy at ural-Design-Group llC. .. 10.08.1970 . 1992 . ( ) ( .. - ) ( ). 2014 -- . Vadim MAKAROV was born in Kungur town in Perm regionon August 8 1970. In 1992 he graduated from Perm Polytechnic university majored in Drilling Oil and Gas Wells. Throughout more than 20 years of working experience he worked in several fields drilling (KungurExploration Drilling Department) oil and gas production (Oil and Gas Production DepartmentKungurneft at present time lukoil Perm) well servicing and workover (Chernushinsk Workover Department Kazakhstan Republic South-Eastern Service Group llC) companies. In 2014 he was appointed to the position of chief engineer at ural-Design-PNP llC. .. 30.12.1984 . 2005 . 2005 2010 - . 2010 -- . Andrey KATEGOV was born in Perm on December 30 1984. In 2005 he graduated from Perm Oil College majored in Geology and Development of Oil and Gas Fields. From 2005 to 2010 he worked as a geologist in PITC Geofizika llC and ural-Oil llC. In 2010 he started working as a geologist in ural-Design-PNP llC at present time his position is chief process engineer. 80 3 (057) September 2016 .. - .. -- .. -- . - ( - -- -- ) . -- . . The leading representatives of uralDesign company are guests of Coiled Tubing Times Journal D. Gaidarji Chief Operations Director Deputy at uralDesign-Group llC V. Makarov chief engineer at ural-Design-PNP llC and A. Kategov chief process engineer at ural-Design-PNP llC. Coiled tubing times group of companies ural-design ( ural-design-group llC uraldesign-PNP llC and ural-design-krS llC) is one of the fastest-growing companies in russian oilfield service market with high technical and technological potential. danila Niolayevich what is ural-design-group s strategy on competition with international service companies danila gaidarji In fact now group of companies Ural-Design is at the same level as international service companies. We offer our customers the same service product line. Coiled tubing times during a long period high-tech service was performed mostly by foreign companies. over the last years russian companies including ural-designPNP llC demonstrate considerable progress in this field. this can be considered as an import substitution isn t it danila gaidarji International companies keep providing services in the Russian market. We don t substitute them we provide the same services at the same level under the same conditions. Coiled tubing times What are the tactics of your company in the market danila gaidarji At present time all contractors compete in tenders organized by oil companies and its subsidiaries. Just like all other service providers we monitor service market and evaluate our technological availability for specific tenders. Coiled tubing times What advantages do you think your company has danila gaidarji Generally from technological point of view we fully comply with all requirements set by major oil companies. We have all the equipment that is stated in customer technical specifications from oil companies and subsidiaries. Coiled tubing times as you can see from the name of our journal we are concerned primarily with coiled tubing. What are the manufacturers of units in ural-design-PNP llC . Throughout 2 years our business was fully transformed into high-technical service. . - . . . 81 3 (057) September 2016 PRACTICE () (). . . . . - . . . 2014 danila gaidarji We operate four units of light medium and heavy classes manufactured by FIDMASH and one unit from Russian manufacturer. Coiled tubing times Can we compare quality of units manufactured by FidMaSH and other manufacturer vadim Makarov No doubt FIDMASH is a leading manufacturer of coiled tubing equipment. . Considering that now many wells are horizontal the only way to convey logging tools to the bottomhole is using coiled tubing. Coiled tubing times vadim Pavlovich the next question is for you. two years ago in September 2014 Coiled tubing times Journal published an interview with you. at that point you were appointed to the position of chief engineer in ural-design-PNP llC with a profound working experience in well workover. How would you evaluate your development in your new role vadim Makarov Last time I was interviewed by Coiled Tubing Times Journal my working experience in this company was as little as 1 week. At that point I was assigned to make adjustments to all departments performance in the first place 82 3 (057) September 2016 . -- . . . . . . . . . . . . Coiled tubing performs effectively three tasks conveying tools to the bottomhole transporting fluids to the bottomhole inflow stimulation by compression method. and then turn to new areas. Throughout 2 years our business was fully transformed into high-technical service. Coiled tubing times did you manage to expand business footprint vadim Makarov Yes it was expanded significantly. Coiled tubing times What about technological expansion vadim Makarov We fully developed standard operations that are indispensible nowadays. These operations include wellbore cleanout well stimulation and milling fracturing ports. We perform these operations at the same level as leading service providers. Coiled tubing times you have an impressive working experience in well workover now you ve gained a significant experience in coiled tubing services. How would you compare these two segments 83 3 (057) September 2016 PRACTICE 20 30 . . . . . . . - . . . vadim Makarov Workover and coiled tubing integration opens up great opportunities. But unfortunately crisis that struck the market doesn t provide comfortable conditions for service companies to develop. Two years ago we were designing several technological projects including sidetracking using coiled tubing. Unfortunately some technologies are postponed till better days. However we make progress and explore new business areas and technologies. . Coiled tubing drilling is a promising technology that is in high demand now. Coiled tubing times What other oil and gas services technologies will be in high demand in your region and russia in the coming years vadim Makarov In the first place that will be a multistage fracturing which is performed globally because this is one of the basic operations for significant production enhancement. Coiled tubing times our journal published a paper from your company about new technology of opening and closing fracturing ports with coiled tubing instead of dropping and milling balls. What can you say about this technology vadim Makarov We carried out this operation on 5 wells in Perm region. andrey kategov Apart from multistage fracturing another promising technology is coiled-tubing-conveyed logging. At present time many fields are at the 3rd or the 4th development stage. That is why logging results are important for customers in order to develop these fields correctly. Considering that now many wells are horizontal the 84 3 (057) September 2016 -10 raNt-M10 . . . . . . . ... . . . . 50 8 . . . . . 2014 . . only way to convey logging tools to the bottomhole is using coiled tubing. In this segment our company provides full range of services. Along with logging we can perform well compression. That means we can solve the tasks that no workover nor logging can handle. That is why I think that the future belongs to coiled tubing. vadim Makarov No doubt apart from multistage fracturing milling and opening closing fracturing ports logging is a highdemand technology because it provides reliable information. Now coiled tubing in conjunction with logging is the most high-technical service in the range of available services. danila gaidarji It is very interesting to work with Novinka CJSC. This company makes a great progress. It is pleasant to communicate with designers that immediately catch any our idea and start developing any technology. The communication is very efficient question answer question answer. We will present our joint projects. Together we can achieve great results. andrey kategov Coiled tubing performs effectively three tasks conveying tools to the bottomhole transporting fluids to the bottomhole inflow stimulation by compression method. Coiled tubing times Coiled tubing drilling was mentioned during our speech. How can you evaluate perspectives of this technology danila gaidarji Autonomous unit with coiled tubing string with 50.8 mm diameter has already been developed as well as special operating procedures and drilling instructions. Thus we have a standard drilling first sidetrack is drilled and cased off then the wellbore is lengthened by drilling with coiled tubing bottomhole motor and a bit after that another sidetrack is drilled. But coiled tubing drilling can be performed effectively only in reservoirs with certain thickness and extension. Belorusneft also performs coiled tubing drilling by using directional drilling system developed by Novinka CJSC. Coiled tubing drilling is a promising 3 (057) September 2016 85 PRACTICE . . . . . . . . .. . . . technology that is in high demand now. vadim Makarov We considered coiled tubing drilling project in 2014 before the crisis struck the market. One of the reasons why this technology is postponed - non-stable economic situation. Coiled tubing times What steps does your Company take to reduce operational costs vadim Makarov Among other things our welders completed training courses on welding technologies. Worn-out coiled tubing section is removed undamaged sections are connected and put back into operation. At present time we provide coiled tubing welding to service companies. Coiled tubing times How do you see the future of high-tech oil and gas service danila gaidarji The future is in the development of high-tech service with coiled tubing units. This segment makes a great progress. More new technologies are being developed and implemented. At present time multistage fracturing is performed in all wells that were drilled. There is an increase in the number of wells in which milling proppant cleanout and stimulation operations can be performed using coiled tubing. There is also an increase in the number of operations on production maintenance and sidetracking in mature wells. These wells are also treated with hydraulic fracturing multistage fracturing and all product line logging in sidetracks stimulation and so on. I m sure that the future belongs to hightech services. andrey kategov In addition it should be noted that high-tech service requires more investments for development. We hope that customers from Russia and post-Soviet countries will invest in new technologies. vadim Makarov Let me take this opportunity to congratulate all employees of the oil and gas industry on the professional holiday Oil and Gas Industry Workers Day. I wish you great success in oil and gas service technologies I with you and your loved ones peace abundance happiness and helth Coiled tubing times let us also congratulate you dear colleges on the professional holiday We wish you success in achieving our common goal interviewer galina yakhontova Coiled tubing times 84119. 86 3 (057) September 2016 3 (057) September 2016 87 .. ktib Holding .. .. .. - ktib Holding ( 3) . . . . 55 56 . 149 150 151 152 153 154 88 3 (057) September 2016 155 156 157 158 159 160 161 162 3 (057) September 2016 89 163 164 165 166 167 168 169 170 90 3 (057) September 2016 171 172 173 174 175 176 177 178 3 (057) September 2016 91 179 180 181 182 183 184 185 186 92 3 (057) September 2016 187 188 189 190 191 192 193 194 3 (057) September 2016 93 195 196 197 198 199 200 201 202 94 3 (057) September 2016 203 204 205 206 207 208 209 210 3 (057) September 2016 95 211 212 213 214 215 216 217 218 96 3 (057) September 2016 219 220 221 KTIB . KTIB . . ( ) (58-) . . . 3 (057) September 2016 97 .. .. (. 1) . . . . (. 2) . (. 3) - . 70 11 1 98 3 (057) September 2016 2 16 3 . () ( ) 1. ( ) . 2. 16 ( ). 3. 12 70 . 4. () 11 . . . 5. () 1400 80 950 . 6. ( 30 3) . 3 . 2015 2016 . 1) ( 48 ). 2) . 3) . 4) . . 3 (057) September 2016 99 - Selection of Aluminum-Polychloride-Based Diverter Composition for Enhanced Oil recovery Operation in Sredne-Khulymskoye Field Formations .. .. .. .. .. .. l. Magadova k. PotESHkiNa M. baltayEva S. kHarlaNov v. dEdECHko gubkin russian State university of oil and gas research and Educational Centre oilfield Chemistry . 25 40% [1]. 55 75% . . () . - () [2]. . . 1 [3 4] 25 60 85 Grace M5600. The effectiveness of oil production with modern developed methods is considered to be low in all oil producing countries whereas consumption of oil products is growing every year. The average overall oil recovery factor in different countries ranges within 25 40% [1]. Remaining or non-recoverable oil reserves reach 55 75% of the original in-place reserves on the average the most of these reserves are located in low-permeable formations. Diverting technologies were developed in order to solve this problem. These technologies increase sweep efficiency by creating watertight barrier in high-permeable formations. However current filtration control methods have some disadvantages. Thus it is important to develop new chemical agents that will enhance oil recovery factor at the existing fields. Research and scientific centre Oilfield chemistry developed compositions for enhanced oil recovery operations based on aluminum-polychloride carbamide and sodium acetate [2]. These compositions are molecular solutions with long gel time that makes possible to create a barrier at a remote distance from the injection well in low-permeable formations. The purpose of this paper is an investigation of main composition characteristics for Sredne-Khulymskoe field conditions as well as selection of composition with characteristics required for conducting enhanced oil recovery operation in this field. Table 1 presents results of an investigation of gel time on developed compositions and its analogues [3 4] at temperatures 25 60 85 as well as investigation of compositions viscosity determined at viscosity gauges Reokinetika and Grace M5600. It should be noted that induction period of gel time and viscosity values are higher when additional agent sodium acetate is used. Since composition 4 exhibits the highest gel time and viscosity values this composition was proposed as an innovative agent for enhanced oil recovery operation in Sredne-Khulymskoe field. When gelling composition is injected in non-uniform permeable formation it filtrates through flooded high-permeable 100 3 (057) September 2016 Table 1 Gel time and viscosity characteristics of developed compositions and analogues ( ) . Gel time h Viscosity MPa s (Sidank classifier code) 25 of compo sition Grace 25 60 85 M5600 4 Reokinetika 1 4 90 23 (I) 4 (I) 2265 32288 . 2 4 84 150 (D) 98 (J) 5 (J) 3797 37179 3 4 78 160 (E) 142 (J) 8 (J) 3560 37906 4 4 66 172 (H) 165 (K) 23 (K) 4674 57688 5 4 60 200 (F) 161 (K) 20 (K) 4341 52737 -1 4 93 21 (I) 3 (I) 2836 29563 . 3 99 42 (K) 6 (K) 2970 34647 -[3] -[4] . Solution Solution Gel Gel - Experiment time h Experiment time h . 1 2 . Figure 1 Fresh-waterFigure 2 Formation based gel time during water-based gel time during stage-by-stage warm-up to stage-by-stage warm-up to (. 1 2). formation temperature formation temperature formation due to its high phase permeability. Since formation temperature decreases during 4 flooding injected composition will heat up to formation temperature only after a definite time period. In terms of studying formation heatup in each part it was decided to carry out mathematical simulation of continuous injection of composition under study in Sredne . Khulymskoye field conditions using simulation program. Received data was used for conducting simulation REFERENCES of continuous composition heatup under formation 1. .. .. .. conditions. For this purpose temperature was increased .. to a certain value during pre-determined time periods . . (fig. 1 2). 2004. 292 . As can be seen from these graphs gradual increase in 2. temperature leads to an increase in induction period of () gel time of composition 4. Considering unbalanced 2529975. composition heatup in formation this process makes 3. possible to create a barrier at remote distances from 2475635. the injection well thus increasing sweep efficiency and 4. consequently production rate. 16554554. Temperature Temperature 1 3 (057) September 2016 101 OILFIELD CHEMISTRY --703 New Bactericide Agent FLEK-BCI-703 .. a. dENiSova FlEk llC ( ) . . () . () . . . 2013 --703 ( 2458-038-24084384-2013). 39-3-973-83 - - (. 1 2). --703 - 100 150 3 - 80 3. 2014 2015 - () --703 iocorrosion of the oilfield equipment and decrease in oil recovery factor (as a result of bridging of formation pores with bacteria biomass or bacterical metabolites) have been becoming more and more significant problems every year. Lack of action or wrong approach to these problems lead to oilfield equipment failure decrease in production rate and eventually environmental disaster. Against the background of low values of pipe steel corrosion rate it was observed that content of hydrogen sulfide in water and iron sulfide in oil has been increased which is evidence of presence of sulfate-reducing bacteria (SRB) and equipment biocorrosion. Well-known method of biocorrosion control is the application of bactericidal corrosion inhibitors (BCI) which is a wide-spread and most effective method so far. Peculiarity of this method is the time point of habituation and adaptation of microorganisms to active components of BCI. Thus it is necessary to find new chemical agents that affect development mechanism of bacterial cells. In 2013 FLEC LLC developed and put in use new bactericidal corrosion inhibitor FLEKBCI-703 (S 2458-038-24084384-2013). Laboratory tests that were carried out according to operational documentation 39-3-973-83 proved high efficiency of this agent in environments infected with bacteria in LUKOIL-Perm LLC and Yukatex-Yugra LLC (table 1 2). Laboratory tests established that agent FLEK-BCI-703 exhibits bactericidal activity for planktonic forms of SRB in infected environments LUKOIL-Perm LLC dosage rate 100-150 g m3 Yukatex-Yugra LLC 80 g m3. Successful pilot testing of bactericide FLEK-BCI-703 in oil-gathering system at Kayumovskoye field was carried out during B 102 3 (057) September 2016 1 --703 - ( 103 50 0%) Table 1 Effectiveness of bactericide FlEK-BcI-703 action on sulfate reduction of SRB in infected facilities of lUKOIl-perm llc (microbial number 103 activity index 50.0%) 3 % Field 25 Moskudinskoye opalikhinskoye baklanovskoye rassvetnoye Pavlovskoye kokuyskoye Shumovskoye 79 83 83 82 79 81 81 50 86 92 87 88 87 88 91 75 90 96 93 94 93 94 94 100 100 100 100 97 98 97 97 150 100 100 100 100 100 100 100 200 100 100 100 100 100 100 100 inhibition effect of bactericide as per its content g m3 % 2 --703 -4 - ( 101 100%) Table 2 Effectiveness of bactericide FlEK-BcI-703 action on sulfate reduction of SRB in bottom water in vertical steel tank - 4 at Kayumovskoye field in Yukatex-Yugra llc (microbial number 101 activity index 100%) ( ) (-) 3 results of samples visual inspection ( ) bacteria growth (-) no bacteria bactericide dosing g m3 50 80 100 150 - - . -1 6 80 3. 3 4 6 9 30 32 1000 1 000 000 3. 100%- --703 ( ) 39-3-973-83 03-00147275-067-2001 . --703 - . the period from October 2014 to April 2015 in Yukatex-Yugra LLC. Constant agent metering was performed by batchng unit 1 6 with the average rate of 80 g m3. SRB content before injection of bactericide in oil-gathering system fluid from well pads 3 4 6 9 30 32 was 1000 1 000 000 kg sm3. Control of bacterial contamination of production fluids during the whole pilot testing period proved 100% effectiveness of bactericide FLEK-BCI-703 for inhibition of bacterial activity (no SRB was detected in fluid samples) that is a positive result according to operational documentation 39-3-973-83 and 03-00147275-067-2001. At present time bactericide FLEK-BCI-703 is injected in oil-gathering system of Kayumovskoye field in Yukatex-Yugra LLC. 3 (057) September 2016 103 OILFIELD CHEMISTRY .. . .. . - - . . . . - . ( ) . ( ). . . () ( ). . . . . . -- . (.. ) ( ). . . . . ( ) . . . . . 104 3 (057) September 2016 . . ... . . - . . . 3 (057) September 2016 105 106 3 (057) September 2016 .. . . . - . - 30-50 2015 MIOGE - 30-40 ( 65276 1010). . . .. . ( ). . .. . . . .. . . 7%. 3 7 . - . .. - . . . (). 3 (057) September 2016 107 . -. - . .. . . . .. () . . ( ) ( ) ( ) ( ) ( ). 13- MIOGE-2015 Intervention Technology award . 2014 (ICoTa-). 108 3 (057) September 2016 - - . . . . - . . . - . . 1) 2) 3) . - - - - - - . . . . . https 3 (057) September 2016 109 110 3 (057) September 2016 . coiled Tubing Times Questionnaire . coiled Tubing Times Questionnaire The following questions were asked 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. () (-) (5 10 ) . In which region(s) does your Company operate Which up-to-date oilfield service technologies are used in your Company Which technologies do you plan to use in the future Does your Company use coiled tubing technologies Coiled tubing units of which manufacturers does your Company utilizes Which coiled tubing technologies are in demand within the area of your Company s activity Does your Company use hydraulic fracturing technology Hydraulic fracturing equipment of which manufacturers does your Company utilize Which hydraulic fracturing types are effective in your region In your opinion which EOR technologies are of vital importance today Which high-tech oilfield service technologies will be in demand in the near term (5-10 years) Which segments of the Russian oil and gas service faced the most serious problems due to the sectoral sanctions 13. How do oil and gas service companies change their approaches of purchasing expensive equipment under current conditions 14. About which oil and gas service technologies would you like to read in Coiled Tubing Times Journal 15. In what directions in your opinion should the Journal expand its topics 3 (057) September 2016 111 . coiled Tubing Times Questionnaire 1. - . 2. . 3. . 4. . 5. . 6. . 7. . 8. 9. 10. 11. () . 12. . 13. . . 14. . 15. . 1. . 2. . 3. 4. . 5. . 6. . 7. . 8. 9. . 10. . 11. . 12. . 13. . 14. . 15. . 1. . 2. Plag and Perf. 3. Plag and Perf. Sergey Smirnov Deputy Director Chief Operating Officer PF Kubangeophysics Gazprom georesurs llC 1. Krasnodar Krai Stavropol Krai Rostov Region and Yamal-Nenets Autonomous District. 2. Full range of information support during well workover and construction operations and development of oilfields. 3. We plan to continue utilization of existing technologies and expand application of new ones. 4. Yes. 5. NOV FIDMASH. 6. Well logging and perforation operations bottomhole cleaning flow stimulation and wells completion. 7. No. 8. 9. 10. 11. In the next year all EOR-related technologies including hydraulic fracturing well logging and stabilization operations will be in demand. 12. All segments face no problems to my mind. 13. Quality and reliability. Now they mean more in comparison with the price. 14. About interesting experience of oilfield service companies and seismic monitoring during hydraulic fracturing. 15. The Journal should publish more materials related to EOR technologies and well logging operations. alexander Novichkov Director Krasnoyarsk branch of ZAO BVT-Vostok 1. Krasnoyarsk Krai Yamal and Tyumen Region. 2. Coiled tubing operations. 3. Hydraulic fracturing with CT application. 4. Yes. 5. NOV FIDMASH and KATT. 6. Well logging and milling operations as well as operations with valves. 7. Not yet. 8. 9. Multi-stage hydraulic fracturing. 10. Hydraulic fracturing bottomhole zone treatments and cement squeeze operations. 11. CT drilling well logging operations and bottomhole zone treatments. 12. Hydraulic fracturing services. 13. If we consider commonly used equipment no changes have been made. 14. About new technologies and equipment. 15. In technologies direction. oleg Skibin director Coiled Tubing OOO Packer Service 1. In Yamal-Nenets and Khanty-Mansiysk Autonomous Districts Samara and Orenburn Regions Bashkortostan and Krasnodar Krai. 2. Well logging operations hydraulic jet perforation and Plug and Perf technology. 3. Plug and Perf technology. 4. Yes. 112 3 (057) September 2016 coiled Tubing Times Questionnaire 4. . 5. Hydra Rig Stewart & Stevenson. 6. . 7. . 8. Frimaer. 9. . 10. . 11. Plag and Perf. 12. 13. . . 14. Plag and Perf . 15. . 1. . 2. . 3. . 4. . . 5. . 6. . 7. . 8. . 9. . 10. . 11. . 12. 13. 14. . 15. . 1. - . 2. . 3. . 4. . 5. 6. . 5. NOV FIDMASH Hydra Rig and Stewart & Stevenson. 6. Bottomhole cleaning well development milling of multi-stage frac ports hydraulic jet perforation and well logging operations. 7. Yes. 8. CAT and Frimaer. 9. Multi-stage hydraulic fracturing. 10. Hydraulic fracturing hydraulic jet perforation and well development. 11. Multi-stage fracturing and Plug and Perf technology. 12. 13. They switch to equipment of domestic manufacturers. Or that of Chinese manufacturers. 14. About multi-stage fracturing and Plug and Perf technology. 15. Well logging operations and bottomhole zone treatments in basaltic perforation zones. Pavel revyakov Process Engineer Well Construction Department BelNIPIneft Belorusneft 1. In the Republic of Belarus and Russian Federation. 2. Radial drilling CT directional drilling and multistage fracturing. 3. CT well logging and CT hydraulic jet perforation. 4. Yes. The following technologies are applied radial drilling CT drilling and injection of cable into coiled tubing. 5. NOV FIDMASH. 6. Radial drilling. 7. Yes. 8. NOV FIDMASH. 9. Acid fracturing and multi-stage fracturing. 10. Radial drilling multi-stage fracturing hydraulic jet perforation and sidetracking. 11. Multi-stage fracturing CT drilling and CT well logging. 12. 13. 14. About multi-stage fracturing with dissolvable balls CT drilling and CT well logging. 15. It should cover more topics related to downhole equipment application. vadim dan shin Head of Production Department RMNTK Nefteotdacha JSC 1. Yamalo-Nenets Autonomous District Orenburg Region Ulyanovsk Region Republic of Belarus and Republic of Kuba. 2. Cement squeeze operations under a license from RMNTK Nefteotdacha JSC preparation and injection of steam into formation and thermal gas treatments. 3. Coiled tubing. 4. Not yet. 5. 6. Well logging operations in horizontal wells selective acid treatments and post-drilling completion of wells. 7. 8. 3 (057) September 2016 113 . . coiled Tubing Times Questionnaire coiled Tubing Times Questionnaire 7. 8. 9. . 10. . 11. . 12. . 13. . 14. . 15. 1. . 2. 3. 4. . 5. Hydra Rig Stewart & Stevenson. 6. . 7. . 8. 9. 10. 11. 12. 13. 14. 15. - 1. -. 2. . 3. . 4. . 5. . 6. .. 7. . 8. . 9. . 10. . 11. . 12. . 13. . 14. . 15. . 9. Acid fracturing. 10. Acid fracturing and hydraulic fracturing. 11. Coiled tubing hydraulic fracturing and steam injection operations. 12. Our service did not encounter any problems. 13. They search for cheaper alternatives. 14. About cement squeeze operations coiled tubing and selective acid treatments. 15. oleg Saakov lead Process Engineer Packer-Service llC 1. Khanty-Mansiysk and Yamal-Nenets Autonomous Districts Krasnoyarsk Krai Orenburg Region and Bashkortostan. 2. 3. 4. Yes. 5. NOV FIDMASH Hydra Rig and Stewart & Stevenson. 6. Bottomhole zone treatments hydraulic jet perforation milling of multi-stage frac ports and well logging. 7. Yes. 8. 9. 10. Multi-stage hydraulic fracturing and hydraulic jet perforation. 11. 12. 13. 14. 15. alexander Zotov Deputy Director Chief Geologist Tatneft-leninogorskRemService llC TagrasRemService 1. Urals-Volga Region. 2. Drilling coiled tubing and hydraulic fracturing. 3. New hydraulic fracturing technologies. 4. Yes. 5. NOV FIDMASH. 6. Well workover hydraulic jet perforation and so on. 7. Yes. 8. NOV FIDMASH. 9. We have different technologies for different cases. 10. Hydraulic fracturing. 11. Various hydraulic fracturing technologies. 12. Software for matrix acidizing operations. 13. The quality of purchased equipment remains number one criterion. 14. About hydraulic fracturing hydraulic jet perforation hydraulic fracturing and well logging operations. 15. CT drilling. Dear readers your feedback will help Coiled Tubing Times Journal to be more useful and interesting for you. Please kindly fill in the questionnaire cut it out scan and send either to cttimes or halina.bulyka . cttimes halina.bulyka 114 3 (057) September 2016 1. ... _____________________________________________________________ 2. _____________________________________________ ___________________________________________________________________ 3. _________________________________________________________ 4. (-) _________________________ ___________________________________________________________________ ___________________________________________________________________ 5. ________________________________________________ ___________________________________________________________________ 6. __________________ ____________________________________________________________________ 7. ______________ ___________________________________________________________________ 8. _________________________________________________________ ___________________________________________________________________ 9. (-) ___________________________________ ___________________________________________________________________ 10. _________________________ ____________________________________________________________________ 11. ___________________________________________________________ __________________________________________________________________ 12. ______________ _____________________________________________________________________ ____________________________________________________________________ 3 (057) September 2016 115 13. ________________________________________________ ______________________________________________________________________ 14. (5 10 ) ____________________________________ ______________________________________________________________________ ______________________________________________________________________ _______________________________________________________________________ 15. ___________ _____________________________________________________________________ _____________________________________________________________________ 16. ________________ _____________________________________________________________________ _____________________________________________________________________ 17. . ___________________________________________________ 18. . ______________________________ ______________________________________________________________________ ______________________________________________________________________ 19. ___________________________________________________ _____________________________________________________________________ _____________________________________________________________________ 20. ______ _____________________________________________________________________ 21. ____________________________________ _______________________________________________________________________ 116 3 (057) September 2016 3 (057) September 2016 117 iii (Xi ) - () .. 24 2016 III (XI ) - . ( ) . .. . 70 24 . . () . .. .. . . . . . . . . . .. . . . III (XI ) - - - . - .. - . 118 3 (057) September 2016 .. . .. . - . .. - . - . . . .. . .. . .. . - .. - - . 16 . . .. . . . . .. .. . . IV - (II - ) 2017 . III - . 3 (057) September 2016 119 The Beauty of Oilfields - . The photos are published by courtesy of the Krasnoyarsk branch of BVT-Vostok. 120 3 (057) September 2016 3 (057) September 2016 121 122 3 (057) September 2016 (ICoTa) - intervention technology award 2016. ______________________ ___________________________________________________________________________ __________________________________ ___________________________________________________________________________ _________________________________ ___________________________________________________________________________ _________________________________ ___________________________________________________________________________ _______________________________________ ___________________________________________________________________________ ________________________________ ___________________________________________________________________________ () _____________________________________________ ___________________________________________________________________________ ____ ___________________________________________________________________________ __________________ __________________________________________________________________________ cttimes 7 499 788 91 19 - . ICoTA . Intervention Technology Award 17- - 10 2016 . intervention technology award 2014 (ICoTA) IoTA ( ). 5 1 224 119017 7 499 788 91 24 7 (916) 512 70 54 7 499 788 91 19 3 (057) September 2016 123 NP CTTDC Dear colleagues and friends Russian Chapter of the Intervention and Coiled Tubing association (ICoTa) invites you to respond to a poll and tell us which companies are worthy of the special intervention technology award 2016. You are kindly asked to choose the companies which in your opinion are the winners in the following categories Best company in the sphere of coiled tubing technologies application in russia and CIS countries ________________ ___________________________________________________________________________ Best company in the sphere of hydraulic fracturing operations in russia and CIS countries ____________________ ___________________________________________________________________________ Best international company in the sphere of hydraulic fracturing operations _____________________________ ___________________________________________________________________________ Best innovating company in russia and CIS countries___________________________________________ ___________________________________________________________________________ Breakthrough of the year the fastest-growing company________________________________________ ___________________________________________________________________________ Best international company on the russian oilfield service market ___________________________________ ___________________________________________________________________________ Best company-manufacturer of the high-tech oilfield service equipment on the territory of the Common Free market Zone__ ___________________________________________________________________________ Financial institution that promotes high-tech oilfield services in russia ________________________________ ___________________________________________________________________________ Best periodical devoted to oil and gas service in russia and CIS countries _______________________________ ___________________________________________________________________________ Please kindly fill-in the form scan it and send to cttimes you can send the filled form by fax as well 7 499 788 91 19 Your opinion is very important for us On the first stage we will form short lists of the companies in each of the categories on the basis of your votes. On the second stage the panel of judges comprising board members of the russian Chapter of ICoTA experts from the russian ministry of Energy members of the Scientific Council of Coiled Tubing Technologies Development Center and members of the Editorial Board of Coiled Tubing Times Journal will choose the winner in each category (according to the elaborated qualitative and quantitative criteria). intervention technology award Ceremony will be held in the framework of the 17th International Scientific and Practical Coiled Tubing Hydraulic Fracturing and Well Intervention Conference on November 10 2016. Intervention Technology Award was established in early 2014 by the russian Chapter of the Intervention and Coiled Tubing Association (ICoTA). It is the russian version of the award established by the US Chapter of ICoTA. Contact information 5 1 Pyzhevsky lane Suite 224 119017 moscow russian Federation Telephone 7 499 788 91 24 7 (916) 512 70 54 Fax 7 499 788 91 19 124 3 (057) September 2016 . (ICoTa-) (ICoTa) . ICoTa- ____________________________ - ______________________________ _______________________ __________ - ______________________________ _____________________________ ___________________________________________________________ _________________________________________________________________________________ ___________________________________________________________________ _________________________ __________________________________________ ______________________ ____________________________________________________________________ ___________________________________ ________________________ 7 499 788 91 19 e-mail info 3 (057) September 2016 125 119017 . . . 5 . 1 224 . 7 499 788 914 . 7 499 788 91 19. - 84119. . ( 3 ). . (3 . 4 .) 13 200 . ( 10%) . cttimes For English-speaking readers we recommend to subscribe for PDF-version of the Journal. Please send your subscription request to cttimes Year subscription price for PDF-version 80 . (rc (halina.bulyka (artem.gribov . .-. (advert cttimes .. ... .. ... . . .. .. C .. Trican Well Service . NOV CTES .. ... . Editor-in-chief Halina Bulyka (halina.bulyka Director of Strategic Development Coiled Tubing Times Artem Gribov (artem.gribov Scientific editor Vasili Andreev Doctor of Phys.-Math. Translators Gregory Fomichev Svetlana Lysenko Executive editor Natallia Mikheyeva Marketing and advertising Marina Kulikovskaya (advert Design & computer making up Ludmila Goncharova Subscription & distribution cttimes Chief scientific consultant V. Voitenko Doctor of Engineering Professor Member of the Russian Academy of Natural Sciences Scientific consultants L. Magadova Doctor of Engineering Deputy Director of Institute of Industrial Chemistry Gubkin Russian State University of Oil and Gas i. Pirch Director of CJSC Novinka H.B. Luft Professor Senior Technical Advisor of Trican Well Service K. Newman Technical Director of NOV CTES A. Kustyshev Doctor of Engineering Professor. Honorary editor Ron Clarke (rc 126 3 (057) September 2016