NP CTTDC
P 11 P W МИНИСТЕРСТВО ЭНЕРГЕТИКИ РОССИЙСКОЙ ФЕДЕРАЦИИ
Supported by the Ministry of Energy of the Russian Federation MW 2010
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GLOBAL TUBING
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Tenaris Tubular technologies. Innovative service. ïðîìûøëåííàÿ ãðóïïà
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he materials of the Сonference of 201 2010 0 and information about the 12th nternational cientific and Practical Practical oiled ubing and Well ntervention onference are available at www.cttimes.org
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he materials of the Сonference of 201 2010 0 and information about the 12th nternational cientific and Practical Practical oiled ubing and Well ntervention onference are available at www.cttimes.org
Proceedings of the 11th International Scientific and Practical Coiled Tubing Tubing and Well Intervention Inter vention Conference
CES Coiled ubing Gains Pace · Contents of the Short Course “Coiled ubing – Equipment, Applications and echnology” · Programme of the Conference · Welcoming speech of L.M. Hruzdzilovich, Chairman of the Conference rganizing Committee · Abstracts of Reports Presented on the Conference · he List of Participants
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CI TI IS PC The 11th International Scientific and Practical Coiled Tubing and Well Intervention Conference, organized by ICoTA (Intervention and Coiled Tubing Association), its Russian representative CTTDC (Coiled Tubing Technologies Development Center) and Coiled Tubing Times Journal, took place on September 15-17 in the capital of Russia in the Renaissance Moscow Hotel. Held under the auspices of Ministry of Energy of the Russian Federation, the event was sponsored by Foremost, Global Tubing, Schlumberger, NOV Fidmash, Tegas and Tenaris. The technical sessions were preceded by a one-day Short Course “Coiled Tubing – Equipment, Technologies and Applications”, conducted by its author Dr. H.B. (Bernie) Luft, , PhD, P.Eng. The 10-hour seminar catered for both beginners and experienced users of coiled tubing. Attendees got information on cutting-edge CT working life testing systems, the influence of mechanical damage on the CT fatigue life, the ways to overcome mechanical damage, and state-of-the-art methods of CT repair in the field and within production facilities. Listeners got acquainted with CT drilling equipment, BHA and directional drilling system structure, short radius CT drilling and sidetracking, including that in underbalanced conditions. Each participant got a Short Course Summary in Russian and a Certificate of Attendance. CT drilling is gaining in popularity in Russia. There is an intense ongoing growth in the sidetracking market which is expected to triple over the next five years. That was the highlight of the introductory speech of Leanid Hruzdzilovich, Head of Scientific Council, Coiled Tubing Technologies Development Center, addressed to conference participants. Hruzdzilovich pointed out that over the 12 years since the first conference on coiled tubing technologies, which was unique in the industry at that time, many positive changes had taken place. New equipment manufacturers and companies have appeared to offer high-quality service and the role of local service companies has matured. The number of coiled tubing units (CTU) operated in Russia has grown from 46 to over 140, and the growth has been much faster than the world average. The number of operations using CTU has grown from less than 1,000 a year to over 10,000. This ten-fold increase has been accompanied by growing sophistication in operations: apart from simple well flushing, cementing and isolation jobs, deep CT drilling has become more widespread. The conference programme included four sessions covering about 30 reports delivered to a hundred participants representing oil producers (Rosneft, Gazprom, Gazprom Neft, Surgutneftegaz, Bashneft, Poltava Oil Company, TNK-BP, etc.), service companies (Schlumberger, Trican Well Service, Weatherford, Kogalymnefteprogress, Ugra Azot Service, CATOBNEFT, etc.), and equipment manufacturers (Fidmash and Novinka Joint Ventures, Packer, Yugson Service, Burenie, RosTEKtehnologii, Foremost, Global Tubing, Tenaris, Tegas, Rosen, etc.). The attendees appreciated diligent preliminary work of organizers in choosing papers and build ing-up the conference programme. The utmost intensity of the 4
proceedings became the hallmark of this year event: every speech aroused great interest, with questions and answers giving a clue to most intriguing technologies and techniques. Significant interest was shown to the report entitled “The Experience of Applying Coiled Tubing Technologies in Tatarstan” by Rubin Akhmetshin (TatneftRemService), outlining the principles of conveyor-type workover, which effectively combines coiled tubing and traditional technologies. No less interesting was a report by Damir Mukhametshin (Bashneft) summarizing the experience of applying coiled tubing technologies in Bashkortostan and highlighting the results of unique intertubular operations performed using the MK-10T unit equipped with 1-in. coiled tubing. Detlef Boss (Weatherford) draw attention of the audience to the use of a hydraulic tubing cutter in Kazakhstan fields in conditions when conventional e-line devices were inoperable. Nikolai Demyanenko (Belorusneft) presented two papers, covering development of coiled tubing technologies, and also experience and effectiveness of hydraulic and acid fracturing in terrigenous and carbonate formations in Belarus. Belorusneft service divisions have fulfilled successful fracturing jobs after purchasing NOV Fidmash complete set of equipment. Lyubov Magadova (Gubkin Russian State University of Oil and Gas) shared her news on penetration tests of polysaccharidic well-killing fluid under conditions simulating hydraulic fracture crack. Alexander Sorokin (Schlumberger) told the audience about the first experience of implementation of acid system MaXCO3 – compound aimed at oil recovery enhancement of carbonate reservoirs. Cutting-edge well intervention technologies in intensively developing producing regions were also brought into sharp focus during the conference. Alexander Uskov (Verkhnechonskneftegaz) told the participants about solving the problems of Verkhnechonskoe oil and gas-condensate field, and Stanislav Zagranichny (Trican Well Service) shared experience of well intervention with coiled tubing on Vankorskoye field. Quite a revelation was the report of Sergei Beryuschev (Welltec Oilfield Services) titled “An Introduction to Well Tractor Technology”, as downhole tractors are still an oddity in Russia. The reports by James Chernik (Foremost), Dmitry Zinin (Burenie Research and Production Association), Yury Shtakhov (RosTEKtekhnologii), Denis Vladykin (Tegas), were also devoted to equipment. Sergei Yurutkin of NOV Fidmash, the manufacturer that has produced 75 percent of all CTU operating in the CIS, informed the audience on the full complex of the equipment for modern hi-tech operations in oil recovery enhancement and well cementing. Ivan Pirch (Novinka of the FID Group) delivered a report titled “Technical Means for Directional Drilling in Coal Bed”, which covered the latest patented solution – the SNB89-76M directional drilling system that has already been field-tested. The paper of Konstantin Burdin (Schlumberger) “Realtime Acquisition of Bottomhole Parameters Data with Coiled Tubing” became a sort of premiere 5
as it was introduced a week earlier in Russia than in Florence at the SPE Annual Technical Conference and Exhibition, where the international presentation of this new technology was held. Discussions, disputes, debates, round table on development prospects of oilfield services, boat trip on the Moskva River… What else shall these three days be remembered for? Without any doubt, the most memorable thing will be faceto-face professional communication that turns colleagues into friends, and unites conference attendees into the club of the like-minded, open to anyone devoted to promotion of new oilfield services technologies.
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“ – qPM, PP ” Dr. H.B. (Bernie) Luft PhD, MSc, B-AppSc, P.Eng., Fellow, CSME Dr. Luft is a Mechanical Engineering graduate with a B.App. Sc. (1967) degree from the University of British Columbia, Vancouver, BC, Master of Science, M.Sc. (1971) and Doctor of Philosophy, Ph.D. (1983) degrees from the University of Alberta. His post-graduate study majors were in the areas of thermodynamics, fluid mechanics, heat transfer and other disciplines involving the thermo-sciences. He has gained more than 30 years of practical engineering experience pertaining to the oil and gas industry with specific emphasis on materials science (welding engineering, corrosion, composite materials, etc.), thermal enhanced oil recovery processes (e.g. SAGD), drilling rig design and manufacture and coiled tubing (CT) research, engineering and manufacturing. He has published over 30 technical papers, 22 of which pertain to CT technologies and holds two patents (ICCT and Concentric CT) and CT spoolable connector the “Duralink” for which he was awarded the Hart’s E&P Int’l Meritorious Engineering Award). Dr. Luft has contributed to the development of Alberta industry guidelines pertaining to sour well operations (IRP-21) and American Petroleum Institute (API) Standards on welding and collapse ratings of coiled tubing. Memberships in technical societies include the Society of Petroleum Engineers (SPE) and the National Association of Corrosion Engineers (NACE). He is a member of Association of Professional Engineers, Geologists and Geophysicists of Alberta (APEGGA) and is a Fellow of the Canadian Society for Mechanical Engineering (CSME) for which he served as VicePresident of the Western Region, Canada. His professional engineering experience includes 15 years as Senior Research As sociate and Group Leader in the Coiled Tubing Research & Engineering (CTR&E) division of BJ Services Company Canada, Manager of the Engineering Department of DRECO involving the design and manufacture of drilling rigs, sub-structures and mud systems, Manager of the Solar and Wind Energy Research Program for the Alberta Research Council. While employed with the Centre for Frontier Engineering Research (C-FER Technologies), he was the National Research Council’s representative as Industrial Technology Advisor (ITA) for the NRC Industrial Research Assistance Program (IR AP). He is a certified Welding Engineer in good standing with the Canadian Welding Bureau (CWB). As Vice President of Technology, Global Tubing LLC responsible for new and advanced technology implementations in coiled tubing manufacturing, new product development, CT failure investigations, customer and sales staff support, Dr. Luft was invited as industry expert and presented a special 1-day course on coiled tubing drilling, fracturing, manufacturing, CT equipment, maintenance and CT operations at the September 2010 ICoTA Conference in Moscow, Russia. He is currently President and Chief Engineer of HBL Engineering Consulting & Research Inc., located in Bragg Creek, near Calgar y, Alberta, Canada. Chapter 1. Coiled tubing equipment Chapter 2. Coiled tubing Chapter 3. Coiled tubing material performance Chapter 4.Coiled tubing Failure Investigations
Chapter 5. Coiled tubing management & maintenance Chapter 6. Coiled tubing applications – Wellbore Cleaning Chapter 7. Coiled tubing applications – Ct drilling and milling 7
Programme of the 11th nternational cientific and Practical oiled ubing and Well ntervention onference Welcoming address of Leanid Hruzdzilovich, Chairman of the Organizing Committee ICota in Russia – New Possibilities for Oil and Gas Specialists. E. Boeke, Senior co-chairman, ICoTA
SESS 1. M W q. M.
Solving the Problems of Verkhnechonskoe Oil and Gas-Condensate Field by Coiled Tubing Application. A. Uskov, Senior CT Engineer, Well Servicing and Workover Department of ОАО VCNG Penetration Tests of polysaccharidic Well Killing Fluid (PSWKF) under Conditions, Which Simulate Hydraulic Fracture Crack. L. Magadova, Deputy-director of Gubkin Russian State University of Oil and Gas An Introduction to Well Tractor Technology. A. McKay, Vice-president, Europe and former USSR, Welltec Oilfield Services Acid System MAXCO3 – Technologies of Oil Recovery Enhancement of Carbonate Reservoirs. A. Sorokin, Senior CT Application Engineer, Schlumberger Challenges of Well Intervention with Coiled tubing on Vankorskoe Field. S. Zagranichny, Project Engineer, Trican Well Service Development of Method for Coiled tubing Surface Passivation in Order to Decrease the Degree of Its Corrosion after Acid Treatments. K. Poteshkina, student, Gubkin Russian State University of Oil and Gas The API Specification for Coiled Tubing Production. R. Stanley, Representative of the Coiled Tube Resource Management, Head of the Working Group of American Petroleum Institute (API) on CT Fatigue Life
SESS 2. W M P M
The Experience of Coiled Tubing Technologies Implementation in Tatarstan. R. Ahmetshin, Deputy Director, Chief Engineer, Tatneft RemService 8
Use of a Hydraulic Tubing Cutter When Conventional E-Line Devices Were Inoperable Facilitates Workover in Giant Kazakhstan Field. D. Boss, Thru Tubing Service Product Line Manager for the FSU Region Experience and Effectiveness of Hydraulic and Acid Fracturing in Terrigenous and Carbonate Formations of Belarusian Field. N. Demyanenko, Director of the Belarusian Research and Design Institute of Oil (BelNIPIneft), Production Association Belorusneft Technical Means for Directional Drilling in Coal Bed. I. Pirch, First Deputy Director of Novinka Coiled Tubing Technologies for Thermal Treatment. B. Luft, Vice-President of Technology, Global Tubing Development of Coiled Tubing Technologies in RUP PO Belorusneft. N. Demyanenko, Director of the Belarusian Research and Design Institute of Oil (BelNIPIneft), Production Association Belorusneft Coiled Tubing Technologies in OAO ANK Bashneft. D. Muhametshin, Chief Expert of the Department for Oil and Gas Production, Treatment and Sales, Bashneft
SESS 3. qPM W Wk P
Advantages of Hybrid Coiled Tubing Drilling Units. J. Chernyk, Vice President, Sales and Marketing, Foremost Full complex of equipment for performing of high-technology oil and gas recovery enhancement and well cementing operations. S. Yurutkin, Head of Sales and Promotion Department of Fidmash Device for Creation of Axial Weight on Drill Bit During Coiled Tubing Drilling. A. Tretyak, Head of the Subdepartment of the Oil and Gas Wells Drilling and Geophysics, South-Russian State Technical University Nitrogen Compressor Units of Industrial Group TEGAS – Important Technical Component of Coiled Tubing Operations. D. Vladykin, Deputy Commercial Director for Development, Tegas Industrial Group Case History of Downhole Tools Produced by RosTEKtehnologii. Y. Shtakhov, Head of Development Department, RosTEKtehnologii Case Records and Technological Capabilities of Coiled Tubing Downhole Equipment Application. D. Zinin, Chief of the Laboratory for Drilling and Workover Operations Equipment, 9
Burenie Research and Production Association
SESS 4. P z, M PP W P
Realtime Acquisition of Bottomhole Parameters Data with Coiled Tubing Utilization. K. Burdin, Chief Engineer of the CT Workover Department, Schlumberger A New Assessment System for Coiled Tubulars. R. Stanley, Coiled Tube Resource Management, Houston, Texas, USA, Chairman, API Resource Group for Coiled Tubulars Prediction of Coiled tubing Lifetime Taking Into Account the Internal Pressure of Process Fluid. A. Molchanov, Head of the Subdepartment of Engineering mechanics, Gubkin Russian State University of Oil and Gas Evolution of Coiled Tubing Supply. Eric Boeke, Tenaris Round table. Development Prospects of Oilfield Services
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Welcoming speech of .M. zz, chairman of the conference organizing committee, chairman of CTTDC scientific council, senior co-chairman of Russian Chapter of The Intervention & Coiled Tubing Association (ICoTA)
Dear colleagues and friends! This conference is the eleventh in succession. As always it gathered together representatives of major oil and gas service and producing companies, as well as spokesmen from oil and gas equipment manufacturing companies. The organizers of the conference are The Intervention & Coiled Tubing Association (ICoTA), Coiled Tubing Technologies Development Centre (CTTDC) and Coiled Tubing Times Journal, which is the main interpreter of the knowledge about new coiled tubing technologies. Representatives of international service companies always took part in the conference, but during the recent years it has been organized in collaboration with ICoTa, which gives her complete international status. I want to express my thanks to our sponsors: Foremost (platinum), Global Tubing (gold), Shlumberger (silver), NOV Fidmash (sponsor of short course), Tegas and Tenaris (sponsors of the conference’s proceedings). The first and at that time the only in Russia specialized conference that was dedicated to coiled tubing technologies took place in far 1998. Particular goals connected with the development of coiled tubing technologies in Russia and CIS countries were set at that time. Today we can state that these goals have been achieved. What are the main landmarks of these twelve years? Our conference, a stable platform for specialists, has appeared and got firmly established. Since 2008 it was the first conference in Russia, which started to offer a full-fledged short course about the newest technical and technological developments, and possibilities of their application. We have started the publication of Coiled Tubing Times Journal, which has become a real guide-book and popularizer of knowledge. According to the opinion of its readers, no other journal on the territory of CIS countries has such a high concentration of information about oil and gas service. New manufacturers of equipment and young companies that perform service operations have appeared during these years. But what, as chemists say, is a takeaway? The quantity of coiled tubing units operating in Russia has increased from 46 to more than 140, the growth rate being larger than the average rate over the world. Spectrum of operations performed has become more complicated. Heretofore these operations were mostly connected with simple flushings. Nowadays this spectrum includes very complicated technological operations, such as water shutoff and sidetracking at high depth. “In 1990s we copied the foreign experience, said in particular, L. Hruzdilovich. Nowadays, such works as underbalanced CT drilling and well completion at the depths of more than 3.5 km, which were done in Surgut, have become the topic for discussion and possibly emulation all over the world. 11
AbSTACTS PTS PSNTD N T CNNC
PM W z A. A. Uskov, Y.I. Gordeev, OAO VCNG K.P. Basanov, K.V. Burdin, Schlumberger Verhnechonskoe oil and gas condensate field (VOGCF), which belongs to OAO VCNG, is a remote field situated at a distance of 684 miles from Irkutsk. Its commercial development started in 2008. The peculiarity of VOGCF lies in its complex geological structure, low formation temperature (53.6 0F), high content of salts and tendency to formation of asphalt, resin and paraffin deposits (in the bottomhole formation zone (BFZ) and the tubing). 80% of operating wells are openhole wells with horizontal end. The length of openhole can reach the value of 1640 ft, its diameter is 6/8.5-in. There is also a tight section in the tubing with diameter of 1.9-in. In connection with the above-mentioned peculiarities of the field there arose a necessity in performing downhole operations with coiled tubing utilization. Coiled tubing project started at VOGCF in August, 2009. At the beginning of operations main project goals were performing of geophysical well logging (GWL), BFZ treatment and after fracturing flushing of well. In connection with field remoteness Shlumberger delivered and brought into service an autonomous nitrogen mini-plant in order to meet the project demands. Following the results of GWL pilot project, which was performed in the horizontal holes of VOGCF with coiled tubing utilization, we obtained important data on the boreholes conditions: the presence of water, asphalt, resin and paraffin deposits in BFZ, openhole sloughing. We obtained valuable information about the flow rates of wells. As a result of performed operations we revealed a number of drawbacks in the method, which was used for wells survey. These drawbacks were connected with the construction of geophysical tool as well as with interpretation methods. There was a necessity in water removal from the horizontal sections of wellbores. Due to subnormal bottomhole temperature and low oil saturation pressure (asphalt, resin and paraffin deposits formation in BFZ) there was a need in complex BFZ treatment. Shlumberger has completed a large amount of lab investigations. Subsequent to the results of lab tests we made a decision to perform a test treatment with the use of complex system CLEAN SWEEP I* (Shlumberger). In the nearest time we also plan to perform BFZ treatment with heat generating reaction utilization. During the period of March – April, 2010 our crew has performed 9 operations of well flushing and after fracturing completion. We have revealed significant problems in the performance of these operations under conditions of VOGCF horizontal wells. 12
P P W k (PWk) , W M k L. A. Magadova, E.G. Gaevoy, V.B. Gubanov, V.R. Magadov, M.V. Trofimova, Gubkin Russian State University of Oil and Gas, Oilfield Chemistry Institute Water based or salt-water based polysaccharidic well killing fluids (PSWKF) are gels on the basis of modified guars (gelling agent GPG-3), which have low viscosity and penetration. Thanks to the addition of thickening agents (thickening agent SPRD) polysaccharidic aqueous gel forms a unified network structure, which effectively blocks air pockets and fractures at formation temperatures up to 212°F. To estimate recovery rate of fracture conductivity after application of PSWKF in after fracturing wells, we performed complex laboratory research. This research included filtration of well killing fluid through a water-saturated sand packed tube with Saint-Gobain (Norton) UltraProp proppant packing of fraction 18/40, as well as determination of the stable value of pressure drop after replacement of water with gel. After that we filtrated water through a sand-packed tube in the opposite direction and watched the dynamics of pressure drop reduction in the course of gel cleanout. Upon reaching of the minimal value of pressure drop we stopped water filtration and performed proppant extraction out of formation model. Accurate determination of PSWKF contamination level of proppant was performed with the help of KCES-100 unit, which measures proppant conductivity. The first part of research was performed with the help of HP-CFS unit using temperature-controlled sand-packed formation model stuffed with Saint-Gobain UltraProp proppant of fraction 18/40. Model was saturated with brine (density – 63.18 lbs/ft3, viscosity – 0.0007 lbs/(ft*sec)). After that a head end of the model was connected with a stand-up high-pressure vessel filled with PSWKF gel. By means of paraffin oil pumping into the upper part of the vessel we secured injection of gel, which does not mix with paraffin oil and has higher density, into a porous medium of the model. PSWKF injection rate was 0.003 ft3/hour. Temperature of the experiment was 176F, which corresponds to the conditions of terrigenous reservoirs at a number of oilfields of Western Siberia and Orenburg region. Preliminary rheogoniometry of PSWKF with rotational viscometer “Rheotest-2” utilization showed that effective viscosity at a shear rate of 170 sec-1 and a temperature of 75 °F equals to 0.05 lbs/ (ft*sec), at a temperature of 176 °F – 0.016 lbs/(ft*sec). Gel filtration was performed at a continuous increase of pressure drop. After 1 threshold volume of gel was filtrated and appeared at the model back end, pressure drop stabilized at the level of 30.45 psi. At the next stage we filtered brine in the opposite direction at the same injection rate as was during gel filtration. We did it in order to compare the stable value of 13
pressure drop obtained during gel injection with the value of pressure drop during brine filtration. Maximal value of pressure drop during brine filtration turned out to be 12.18 psi. Consequently, during the process of well development in order to perform gel cleanout one need to apply far less pressure than that required for its injection. Brine filtration at a given injection rate continued till the value of pressure drop (measured with differential pressure meter) reached the zero level. After that the process of filtration was stopped. Removal of proppant out of the formation model showed partial presence of gel at a depth up to 1/5 of the model length. It is obvious that in ordeer to remove this gel we need additional brine filtration. Nevertheless we took samples of this proppant and proppant from the other part of the model (with liquid phase) for further investigations at KCES-100 unit (determination of proppant conductivity and level of PSWKF gel contamination of proppant). It is necessary to mention that proppant Saint-Gobain UltraProp of fraction 18/40 was chosen (because of its high strength) in order to eliminate the influence of proppant mechanical breakdown on its conductivity. Moreover, tests were performed in a conductivity cell at a minimal compression pressure of 1000 psi. Experiments were conducted at a room temperature (75 °F). The value of gel viscosity at this temperature is more than at formation temperature. The results of investigations are shown in Table 1. As one can see in the table conductivity restoring coefficient of two proppant samples with reference to conductivity of a clean proppant slug after PSWKF injection is equal to 54.31% for proppant from the most polluted part of the model and 89.09 for proppant from the other part of the formation model. The obtained results allow recommending the application of PSWKF for after fracturing well killing. Table 1 The results of comparative investigations of proppant conductivity
Characteristics
Values
Proppant, Designation, fraction
Saint-Gobain (Norton) UltraProp 18/40
Proppant load, lb/ ft 2
2.0
Compression pressure, psi
1000
Exposure time, hours
2
Temperature, ° F
75
Conductivity of a clean proppant slug, mD*ft, tested at injection rates of 0.01, 0.02 and 0.03 ft 3 /hour
13906
14
Proppant slug from the sand-packed model after PSWKF treatment
Sample #1 (from 1/5 of the model length)
Sample #2 (from the other part of the model)
Conductivity of proppant slug from the sand packed model, mD*ft, tested at injection rates of 0.01, 0.02 and 0.03 ft 3 /hour
7553
12389
Conductivity restoring coefficient, %
54.31
89.09
Besides, these results are in agreement with the previous results of PSWKF investigations obtained at OAO NPC Tver’geophizika using nuclear magnetic resonance method and penetration tests of core samples (Investigations of the impact of well killing fluids and acid solutions on clogged terrigenous reservoirs / T.V. Hismetov et al.) // Neftyanoe hozyaistvo. - 2007. – Vol. 3. - P. 92-95).
PP W A. McKay, Welltec Oilfield Services S.E. Beryuschev, OOO Welltec Oilfield Services (RUS) Welltec Oilfield Services is one of the major companies that provide services with utilization of downhole tractors and other lightweight mechanical devices, which provide an alternative to well intervention technologies that use such heavyweight equipment as conventional workover and coiled tubing units. The company started its operation in Russia in 2008. At first its services were connected mostly with conveyance of logging tools and perforators to horizontal wellbores with the help of downhole tractors. Now on the Russian oil and gas market Welltec provides its customers with other types of services, such as milling, bottomhole cleaning and other e-line controlled mechanical operations. Using these technologies our clients immediately obtain the result owing to application of faster, safer and more effective (with relation to cost optimization) service. Utilization of Welltec equipment significantly simplifies logistics during well intervention operations due to its low weight and small size. Besides, utilization of this equipment essentially increases operational safety at the expense of job duration time reduction, decreases the number of engaged personnel since in most cases there is no need to use conventional workover and coiled tubing units. Nowadays the company provides its services in all regions of Russian Federation. Conveyance of equipment to horizontal wellbores with e-line downhole tractors utilization is in demand among Welltec customers because of its economic effectiveness, better operational and ecological safety. 15
M MX3 – M A.N. Sorokin, I.V. Chen, K.V. Burdin, Shlumberger V.V. Kunavin, R.E. Zontov ,OOO Gazprom dobycha Astrahan’ During three years of collaboration between Shlumberger and OOO Gazprom dobycha Astrahan’ in the sphere of utilization of coiled tubing for well workover operations at Astrahanskoe gas condensate field (AGCF) we performed a huge volume of work on selection of technologies that allow performing operations under conditions of AGCF. In Coiled Tubing Times journal we continually told about utilization of coiled tubing in the wells of AGCF. In this report we will consider a technology of selective treatment of carbonate reservoirs with the use of acid system MaxCO3®. This technology has been applied in Russia for the first time. Acid treatment of bottomhole zone in gas wells with productive zone thickness more than 656 ft is connected with a number of difficulties. Performing of highquality treatment of the whole interval is a very complicated task. Situation at AGCF is redoubled by a complex well design – production interval is overlapped by a blank liner by 80-90%. This limits access to upper and middle parts of production interval and forces to perform acid treatment of bottomhole zone through the lower part of interval. This process is accompanied by the raising of stimulation fluid in the annulus along the whole formation. Such operation is impossible without utilization of high-quality systems of acid deflection, especially in the presence of high-permeability layers and fractured zones that are common for carbonate reservoirs. Utilization of coiled tubing, besides other traditional advantages over well workover, allows performing of borehole and tubing cleanout before acid treatment. This helps to avoid additional contamination of bottomhole zone. Utilization of JetBlaster® bottomhole tool and water jet effect enables to remove filter cake and cement leavings. Application of polymer deflecting systems is impossible due to aggressive formation conditions – formation fluid acidity, presence of hydrogen sulfide (molar concentration up to 25%), formation temperature up to 230 °F, formation pressure more than 8700 psi. A significant drawback of polymer systems is that they cause residual contamination of formation matrix. Taking into account all above-mentioned peculiarities of AGCF Shlumberger has introduced complex approach of AGCF wells maintenance. It includes a large number of operations on borehole cleanout from sediment and contaminants, as well as a full complex of bottomhole formation zone treatments. Besides successful and proven VDA system, last introduction of the company was the application of acid system MaxCO3 – the newest polymer-free system for 16
carbonate reservoirs treatment, which has been applied in Russia for the first time. The advantage of this technology consists in complex (chemical and physical) temporary blocking of the most permeable (drained) zones. Increasing of the efficiency of chemical blocking, which is performed by VDA system, is realized due to utilization of dissolvable fibers of prolonged action. Owing to these fibers active acid is transported directly to weakly drained part of formation, which is saturated with hydrocarbons. Currently we have performed a pilot selective acid treatment of AGCF well with MaxCO3 system utilization. As a result of utilization of multi-stage treatment program with 15% solution of hydrochloric acid (HCl) as a basic fluid we got a 200% increase in productivity.
W W kk Suleyman Sitdikov , Rosneft Stanislav Zagranichniy, Trican Well Service The article reviews the engineering, operational and logistical issues related to utilizing coiled tubing in Vankor oil field and the innovative solutions required to overcome these issues. The Vankorskoe field is a one of the major sources of Rosneft’s production growth in the mid-term, and was launched in the second half of 2009 The Vankorskoe field has all the wells drilled on pads. Each pad has multiple wells drilled on it, all at different trajectories to maximize the contact to recoverable reserves. Each well is drilled with a complex trajectory into the producing zone. The wells are designed with a reverse bend in it allowing the horizontal section of the wellbore to be directly beneath the wellhead. The field is drilled primarily with horizontal wells, 75% of which have smart completion. Two sizes of coiled tubing are used in the Vankorskoe field, 38.1 mm and 44.45 mm. The 38.1 mm is used in wells were downhole completions or restrictions prevent the use of the 44.45 mm coiled tubing. The 44.45 mm coiled tubing is the work string used on the majority of the treatments performed. These treatments, to date, are clean outs, kick offs, stiff wireline logging and hydrate removals. The complicate well profile demands the special approach for intervention techniques. In the given well profiles, conventional wireline techniques are not appropriate to convey tools the producing intervals. On the other hand, Coiled Tubing is well suited to conduct such operations in the extended reach wells. The definition of an extended reach well is a well with a measured depth to true vertical depth ratio (MD/TVD) greater than 2.0 which is very applicable for Vankorskoe field wells profile. The coiled tubing technology is used for 17
wellbore cleanout operations after the completion and workover, well kickoff and production logging. The string lengths vary from an average of 4059 m for the short strings to an average of 5757 m for the long strings. The wireline installed in the stiff wireline strings is a seven conductor, double armour style. There are currently 2 stiff wireline strings, 44.45 mm, which for logistical reasons are long strings. The single most persistent issue encountered so far in the Vankorskoe field is the inability to get the coiled tubing to TD. There are multiple possible reasons for this, ranging from wellbore deviation, dog leg severity, wax build-up, well bore completions, residual drilling or workover debris, equipment malfunction and operator error. As the Vankorskoe field continues to grow, with more wells coming on line, the role of the coiled tubing units are also changing. In order to meet the current challenges and to address the changes in operations, new technologies are being investigated to work in the Vankorskoe field. Some ideas are old technology, proven in the past in other oil fields, but so far, have not been used in Vankorskoe, others are custom solutions to be used on the unique challenges provided by these wells.
PM M P M M.A. Silin, L. A. Magadova, L.F. Davletshina, O.Yu. Efanova, K.A. Poteshkina, Gubkin Russian State University of Oil and Gas Most of the oil fields on the territory of Russian Federation are under production stage, which is characterized by decreasing production rates because of the gradual depletion of their reserves. That’s why it is very important to apply oil production technologies that allow restoring and often even improving filtration characteristics of reservoir, as well as increasing oil recovery factor. The most promising and important technologies of production stimulation and oil recovery enhancement are those with coiled tubing (CT) utilization. The main advantages of these technologies include mobility and low time and material costs of well workover operations. Taking into account the complexity of RIH and POOH operations, operations on injection of corrosive medium through CT system, a question of CT wear resistance is investigated by various scientific institutes. The main part of investigations is connected with the study of CT fatigue during reel-in/reel-out. The problem of CT corrosion is usually given little attention. At Chemicals Technologies for Oil and Gas Industry Department of Gubkin Russian 18
State University of Oil and Gas the investigation of corrosion of steel, which is used for CT manufacturing, has been performed. Chemical compounds on the basis of SKA modifier for CT surface passivation have been developed in order to decrease the degree of CT corrosion after acid treatments.
P P (5) P R.K. Stanley, Coiled Tube Resource Management We review the new standard (5ST1) for the production, testing and nondestructive inspection of coiled tubing, and compare it with the existing standard for coiled line pipe (API Spec 5LCP2) The former contains a customer requirement for fullbody inspection after hydrostatic test, while the latter requires only a re-inspection of the full length seam weld. 5LCP material must pass all the requirements of 5LCP and can be made from a variety of steels. There are no fatigue requirements, and neither are there in 5ST. ASTM A606/7 steels are commonly used for both coiled tubing (CT) and coiled line pipe (CLP), although other steels could be used for CLP. There is no mention of these steels having to pass any NACE tests, although these might be ordered by the customer. Following the hiatus to develop 5LCP, the Resource Group for Coiled Tubulars (RGCT) returned to the development of 5ST, which was finally accepted in April 2010. The final document covers the grades, sizes, wall thicknesses, destructive and non-destructive tests (X-ray, electro-magnetic, ultrasonic) for the tubes, and finished welds. Grades are CT70, CT80, CT90, CT100 and CT110 only. 5ST and 5LCP are manufacturing documents. As such they contain no information about operation in sour service, because the RGCT did not feel that enough was known about the performance of the then-manufacturer’s grades in sour service. Further, the wide spread of data from fatigue machines, the variations in fatigue machine design, and the different steels used to produce CT do not permit comment with regard to standardization. Rather, general comment on the fatigue life issues is better suited to a recommended practice or technical bulletin than to a manufacturing standard.
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R.M. Achmetshin, OOO Tatneft-AktyubinskRemService OOO Tatneft-AktyubinskRemService delivers services in the sphere of well wokover with coiled tubing technologies utilization. Our major customers are Oil-and-Gas Production Department OAO Tatneft, Tatburneft, enterprises that form a part of Tatneft-Remservice and small oil producers. We have used coiled tubing technologies since 1998. More than 6000 wells of different function have been repaired and more than 400 conventional workover operations have been performed since that time. We have also mastered 32 technological operations. Every year we perform more than 700 treatments with coiled tubing units’ utilization. Operations are usually carried out in the Republic of Tatarstan, Samara and Orenburg regions.
With application of coiled tubing we perform almost full spectrum of workover operations: Control of oil deposits development: • reservoir part shutoff; • reservoirs and horizons shutoff; Production stimulation: • underbalanced bottomhole zone treatment (BZT); • overbalanced BZT; • vibrowave action; • preparation of wells for oil enhancement operations; • annular space operations; • preparation of wells for acid hydraulic fracturing; • preparation of wells for sidetracking. Special operations: • abandonment and reabandonment of wells; • pipelines flushing; • selective access to wellbores of multilateral wells; • operations at bituminous wells. • Full spectrum of conventional workover services: • after fracturing proppant cleanout; • stuck tubing cutting-off; • cleanout of bridged tubing; • well killing; • production string reaming; • drilling out of cement plugs. 20
The main part of operations is occupied by BZT of injection wells, bottomhole flushing with solvents utilization and well stimulation through annular space. We also perform small amount of water shutoff operations, reservoir shutoff and tubing sealing operations, after drilling development of wells and after fracturing proppant cleanout. We can exclusively perform operations of fiber-optic cable reeving into coiled tubing and subsequent lowering the coiled tubing into bituminous wells to control formation warm up and to deliver logging tools during horizontal wells survey. Since 2003 we use the method of well workover without pulling-out of downhole pumping equipment. In the framework of this method 1'' coiled tubing is lowered down via annular space through a hole for geophysical survey in the handing flange of wellhead equipment. Method is used in the wells equipped with sucker-rod pumps. More than 1000 workover operations have been performed during this period. The main part (more than 800 wells) of them falls at BZT for the purpose of production stimulation. There is also a small amount of operations connected with injection of chemicals for oil recovery enhancement and solvents for asphalt, resin and paraffin deposits removal. This year for the first time we have successfully lowered down coiled tubing into the annular space of a well equipped with electric submersible pump. It means that in the annular space we had both the coiled tubing and a domed rubber armored cable. There were no problems during the coiled tubing lowering down and pulling out operations. Successful performing of these operations creates additional possibilities for expansion of coiled tubing applications. Next technology is a selective access to wellbores of multilateral wells. Currently in OAO Tatneft there are more than 100 wells with two, three and four wellbores. In order to reduce costs and increase the success rate of operations in these wells we use universal hydraulic coiled tubing deflector OGGTU 90-1, which is intended for accessing two or more wellbores of multilateral well in a single run and subsequent BZT of them with various chemical agents. We continue operations at bituminous fields that are operated using steam assisted gravity drainage method. Starting from 2008 OAO Tatneft uses the technology of investigation and isolation of water inflows in horizontal wells with inflatable packers’ utilization. The technology includes performing of geophysical survey operations with the help of coiled tubing and identification of water- and oil-bearing sections in openhole horizontal wells. By lowering down the inflatable packer we perform separation of oil-bearing section with the possibility of further carrying out of isolating operations in the water-bearing section of formation. During this operation we have revealed a set of drawbacks connected with utilization of inflatable packers. There were problems with hermiticity after packer 21
setting (perhaps, due to the state of walls in the openhole or filtration of liquid through formation); packer releasing occurred during the process of chemicals injection. In order to increase the efficiency of operations there were suggested to use hydraulic fracturing fluid (polysaccharidic gel with decomposition after 48 hours) as a packer. The volume of injection should be equal to the volume of the oil-bearing section of the openhole. Estimated volume of polysaccharidic gel was prepared directly at the wellsite with the help of standard equipment and there was no need in special training of servicers. Conveyance of gel to the preselected interval was conducted with coiled tubing unit utilization. Isolating operations were performed in 17 horizontal wells; in the eight of them we used gel as a packer. The analysis of performed operations shows that the quality of water shutoff operations does not decrease when using the “liquid” packer. In 2010 we tested the technology of crossover circulation of wells through 1-1/2'' coiled tubing. Thickened solutions (0.08-0.1 lb/(ft*s) viscosity) were used as process liquids. Given technology in conjunction with solvents application allowed to better prepare wells for geophysical survey. OOO Tatneft-AktyubinskRemService is always looking for innovative methods of well workover that increase the number of used coiled tubing technologies and the efficiency of workover operations. We do not try to compete with conventional well workover. We significantly expand the possibilities of well workover operations.
W - W P Wk kzk Detlef Boss, Weatherford International Ltd. The Kashagan East field, located in the North Caspian Sea contract area in Kazakhstan, was discovered in July 2000 and is one of the most significant discoveries in the past 30 years with recoverable reserves estimated at 7-13 billion barrels of oil from the deep high pressure reservoir. Production is of 45°API light crude with a high gas/oil ratio having H2S content in the region of 19%. Development of the field continues with first production anticipated in 2012 and, as a result of the production characteristics, wells are typically completed with a single string of 25% chrome tubing to an integral permanent packer with all completion components being either Inconel 718 or 925. In 2007 while performing a routine tubing caliper survey on a completed well, the cable head released and the caliper tool string fell to bottom. Subsequent efforts to fish the caliper using heavy duty wireline and coil tubing methods failed and it was left 22
in the hole at a depth of 4688 meters (15,381 ft.). Over time settlings and swarf from the tubing covered the fish to where it acted as a check valve, hindering any pumping into the well, but allowing bottom hole pressure to pass, and so it was decided to work the well over. This necessitated cutting the tubing above the packer and, to use an electric line conveyed Radial Cutting Torch (RCT), it was first necessary to punch holes in the tubing, close to the intended cut area, because the fish acting like a check valve would eliminate the shockwave compensation created by the RCT. However attempts to punch holes as required failed for reasons as yet unverified and so the only available alternative was to run a coiled tubing conveyed hydraulic cutter powered by a downhole motor, since it only required circulation to surface and no punched holes. This was run successfully and the tubing was cut in a period of 35 minutes allowing the planned workover to continue. In this paper the author will review the background history of the well and the series of events that led to the need to work it over. He will go on to describe in detail the problems that were faced in attempting to cut the tubing and the hydraulic cutting mechanism and operation that overcame them.
MP P I.Ya. Pirch, SZAO Novinka, FID Group For many oil and gas companies implementation and development of coiled tubing directional drilling technologies, including underbalanced drilling, is economically prospective. This technology is rather effective for preservation and even increase of hydrocarbons production level both at mature and green fields. Also coiled tubing directional drilling technology can be effectively used for well drilling in coal beds. Success and effectiveness of coiled tubing technologies applications in many respects is determined by the reliability and effectiveness of utilization of special BHA’s that operate as part of coiled tubing complexes. For this purpose SZAO Novinka created the corresponding equipment – directional drilling system DDS89. In order to achieve the above-mentioned purposes FID Group is ready to present a special coiled tubing complex. This complex is based on coiled tubing equipment and directional drilling system DDS89, which provides the possibility of directional drilling of all well types, including horizontal wells and formations of various thicknesses. DDS89 system includes BHA and a set of surface equipment that provides communication with downhole equipment and its proper operation, as well as processing and visualization of data received from measuring units. 23
Bottomhole assembly (for directional drilling system – with wireline communication channel) includes a set of elements that provide measuring and recording of: inclination angle, azimuth, the angle of downhole drilling motor (DDM) steering tool arrangement, temperature, pressure on DDM, annular pressure, weight on bit, level of rock’s natural gamma-activity and BHA vibration level. Orientator, which forms a part of directional drilling system, provides control of drilling direction in order to secure a predetermined well trajectory. Circulation valve is used for alteration of drilling fluid flow direction without passing through DDM. It is also used when there is a need to disconnect the lower part of BHA from the upper one. Communication with surface equipment is realized via electric cable that goes through coiled tubing. For operation as part of conventional complexes SZAO Novinka is ready to offer directional drilling system with hydraulic communication channel. Communication with surface equipment in this case is realized by means of pulser utilization. Pulser forms a part of BHA and transmits information via drilling mud column. Directional drilling systems with hydraulic or wireline communication channel are offered by SZAO Novinka in two modifications: 3» or 3-1/2» diameter.
PM P P N.A. Demyanenko, M.I. Galay, U.A. Butov, A.I. Gavrilenko, D.L.Tret’jakov, A.N. Bogatko, BelNIPIneft RUP PO Belorusneft Applicability and practicability of coiled tubing technologies utilization is determined by the necessity of application of more effective measures for extraction of remaining and hard to recover reserves. For the last 3 years coiled tubing technologies have been applied at the fields of Belarus too. Performing of oilfield coiled tubing operations at bottomhole zone is provided by MK-30T unit. Unit works in conjunction with coiled tubing of 1-1/2», 1-3/4» and 2'' (for sidetracking) diameter. The results of coiled tubing operations connected with washing of bottomholes of injection wells and flushing of production strings with fluid or foam, removal of salt and paraffin plugs, after fracturing “Stops”, production stimulation (hydrochloric bath, acid treatment), development of wells with utilization of nitrogen unit and compensation technique, as well as with well development after acid fracturing, are represented in the report. We introduce the results of pilot field operations, which were performed in well #289 of Rechickoe field with application of the developed technology and equipment that orient coiled tubing into the sideholes of multibranch well. These 24
sideholes allow performing of selective treatment of each borehole in order to increase well production rate. According to perspective plans of construction of wells with complex hole paths and approbation of underbalanced drilling technologies we present the results of directional drilling system (DDS) field tests in the well # 9012 of Kotelnikovskoe and well # 44 of Novo-Sosnovskoe fields. Following the results of the field tests it can be concluded that DDS, despite of some construction omissions, is serviceable and can be used for hole drilling.
k D.M. Muhametshin, OAO ANK Bashneft Today OAO ANK Bashneft steadily holds leading positions in Russian oil sector because of its high rates of production volumes increase. Drilling of new wells is the most capital intensive part in the structure of costs of all oil production process. That’s why specialists from Oil Production Department of our company pay special attention to optimization of existing well stock operation. Obviously, it is impossible to achieve this goal without recruitment of well workover crews. Specialists of Bashneft today carry out different kinds of operations in order to optimize costs. There are already some results, including those connected with service costs optimization. Against this background coiled tubing technologies appear to be extremely actual and prospective. All seven coiled tubing units that service Bashneft well stock are 100% busy. Mainly (6 out of 7 units) they are busy performing operations that support injection well stock. In particular, on the fields of OAO ANK Bashneft we have introduced technologies of complex bottomhole formation zone (BFZ) treatment of injection wells with utilization of hydrocarbon solvents and acids. Also there has been introduced a method of well hydroswabbing (drainage by means of water injection and subsequent bleeding with formation energy utilization). Operations success is 96.3%. The major obstacle on the way to achievement of 100% success is the unfitness of wells for workover operations (perforation interval shutdown, the presence of thickened adapters in a tubing string, packers with small diameter of the opening, leakage of installed packers). We have also introduced technologies of acid, foam-acid and oil-acid treatments. Besides, the company has a unit that allows to perform operations in the annular space without any preliminary steps connected with preparation of a wellhead and a pump jack. This unit is the only in Russia, which has light injector with pulling capacity of 17,650 lbs. By this moment the unit has performed 92 operations in the annular space, which has allowed to produce additional 24,248.5 tons of oil. 25
D.F. Chernik, M.M. Kursakova, Foremost Industries LP We consider the advantages of hybrid coiled tubing rigs, which were manufactured by Foremost, in comparison with conventional rigs on the basis of practical data received from customers of Foremost. In the first part we give the definition of hybrid coiled tubing rigs. Then we give general information about Foremost Company and the number of hybrid coiled tubing rigs that have been manufactured by the company since 2001. By this moment the company has manufactured 64 rigs, the largest of which weights 150 tons. In the next part we list the major customers of Foremost Company in North America – Nabors Industries Ltd., Trailblazer Drilling Corporation, Xtreme Coil Drilling Corporation. After that we pay attention to the main advantages of hybrid coiled tubing rigs. The first advantage is their universality. The second advantage is their high performance, i.e. the number of drilled wells in a definite period of time. It is verified by the results received from Foremost’s customers. We focus on the fact that utilization of hybrid rigs allows to reduce drilling time in comparison with conventional rigs. The third advantage is the drilling depth. On March 29th, 2007 Xtreme Coil Drilling Corporation jointly with EnCana Oil and Gas Incorporated set a new world record in the depth of drilling (8,123 ft). The record was set in Colorado; the drilling operation was performed with utilization of Foremost’s hybrid coiled tubing unit. Another feature of hybrid rigs is their safety. It is provided by the presence of automatic platform for tubes, tubing elevators and top drive system. Those components minimize the contact of operator with a rig during operations with tubes, eliminating the necessity to use personnel at the wellsite. Besides the abovementioned advantages we emphasize that rig-up time of hybrid rigs is very small – between 2 and 8 hours in Canada. Also in the report we give a review of technical characteristics of Foremost’s hybrid coiled tubing rigs’ components – injector head and top drive. Top drives can be noted for their compactness and excellent “power weight” ratio. They can be easily adapted for most of coiled tubing units used in Russia.
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MPX qPM PM - M W M P A.M. Verigo, leading expert of Sales and Products Promotion Department, NOV Fidmash S.V. Yurutkin, head of Sales and Products Promotion Department, NOV Fidmash Life dictates its own rules, that's why under conditions of severe competition the necessity in application of new technologies moves to the forefront. Therefore, the demand for state-of-the-art, high-technology equipment also grows. In particular, a very important role over that period plays an effective cooperation between manufacturers and service companies. This cooperation results in creation of equipment, which satisfies the most severe technological requirements. Fidmash is not the exception. The company continuously cooperates with its customers and improves standard models of equipment, designs and manufactures the newest machinery and upgrades previously produced units.
In this report we present complexes of equipment for performing of high-technology oil and gas recovery enhancement and well cementing operations, namely: • cement squeeze; • bottomhole zone treatments; • remedial actions; • well logging with coiled tubing utilization; • coiled tubing drilling, including underbalanced drilling; • hydraulic fracturing; • well cementing; • and so on. We also present new equipment and modifications of standard units developed by NOV Fidmash specialists: • coiled tubing unit MK30T-60 with Terberg (Volvo) chassis; • coiled tubing unit MK30T-40 capable of operating both at onshore fields and offshore platforms (modular construction mounted on a chassis); • two-pump cementing unit H1000C with automatic cement preparation system; • associated equipment In addition we present a review of standard technical equipment, possibilities of spare parts delivery and rendering of maintenance services.
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X W A.Ya. Tret’jak, Yu.F. Litkevich, A.E. Aseeva, South-Russian State Technical University (SRSTU (NPI)) Generation of weight on drill bit during coiled tubing drilling (CTD) is a relevant objective nowadays. During the process of horizontal drilling, especially when the length of horizontal section is considerable, most of the axial load is lost on the way to bottomhole. At present time there are several devices for generation of weight on drill bit. Bashkir State Institute for Oil Refining and Petrochemical Industry Plants Designing (patent №2006563), NPO Burovaya Technika – VNIIBT (standard series commercial output) and Tyumen State Oil and Gas University (patent №2124617) offer the device on the basis of hydro loader. SZAO Novinka of FID Group and BP company propose to generate weight on drill bit with the help of downhole tractor. Developments of all organizations, except VNIIBT, are of experimental character. Staff members of Oil and gas wells Drilling and Geophysics Department of SRSTU (NPI) have developed a method of generation of axial load on horizontal well bottomhole and a corresponding device for its realization. The essence of method lies in generation of axial load by a single or a set of tandem assemblies, which consist of hydraulic kicker and hydraulic power cylinders. Principle of device operation consists in the following: a power cylinder, which has a piston inside, is connected with drill pipes by means of square joint (splined tube assembly). Hydraulic kicker and hydraulic power cylinders rods have channels for circulation fluid. Hydraulic power cylinder is connected with hydraulic kicker cylinder by means of coupling joint. Together they form an assembly. Hydraulic kicker cylinder has a piston, arbitrary motion of which is prevented by a spring. The rod of this cylinder, which has a channel for circulation fluid, is connected with the rod of hydraulic power cylinder by means of a valve. When the pressure of circulation fluid is not enough to start the operation of downhole drilling motor, drilling tool does not rotate and there is no axial load. Circulation fluid just performs flushing of bottomhole. With pressure of circulation fluid increases DDM starts to rotate drilling tools. The piston of hydraulic kicker cylinder compresses a spring and its rod pushes the rod of hydraulic power cylinder out of the valve so that circulation fluid travels into hydraulic power cylinder bottom (head end) through a calibrated orifice. Hydraulic power cylinder generates axial load and performs axial movement on the length of stroke.
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MP P – MP MP P D. Vladykin, Industrial group TEGAS Increase in coiled tubing utilization at the facilities of oil and gas industry. Industrial safety of facilities. Requirements and regulations. Nitrogen – recommended industrial gas for coiled tubing applications. Options of nitrogen delivery to the facilities of oil and gas industry. Nitrogen compressor units – important technical component of coiled tubing operations. Coiled tubing operations performed with nitrogen compressor units’ utilization. Technical capabilities and design variants of nitrogen compressor units. Industrial group Tegas – manufacturer of the extended range of nitrogen compressor units of increased capacity. Differential characteristics of nitrogen compressor units manufactured by Industrial group Tegas. Application of nitrogen compressor units manufactured by Industrial group Tegas at oil and gas facilities. “Nitrogen modernization” of air compression units of different manufacturers Maintenance department possibilities, variants of service maintenance of nitrogen compressor units. Conclusion.
XP PP W M PP k W Yu.N. Shtahov, OOO NPP RosTEKtechnologii One of the main directions of OOO NPP RosTEKtechnologii’s activity is development, manufacturing and delivery of downhole tools intended for well workover operations with coiled tubing units’ utilization. The above-mentioned tools allow to perform the following types of operations: • well cleanout; • well completion; • bottomhole zone treatments; 29
• water shutoff operations; • fishing operations. According to statistics taken form different sources, the main types of coiled tubing operations in Russia and CIS countries are well cleanout and completion operations, bottomhole zone treatments and fishing operations. In this connection the most popular assemblies are the following. 1. Well cleanout and completion: • milling adapter; • flapper-type backpressure valve; • jetting nozzles. 2. Fishing operations: • milling adapter; • flapper-type backpressure valve; • emergency breaker switch; • overshots, wireline catchers, special catchers. The main requirements for manufactured tools are their reliability, resistance to impacts of aggressive environment and maximal overhaul period. In order to determine these parameters our company jointly with OOO Integra-Service and OOO Gazprom podzemremont Orenburg performed successful bench and borehole tests of well cleanout assemblies, including a milling adapter, a flappertype backpressure valve and a jetting nozzle. A significant part of coiled tubing operations is connected with fishing of broken wirelines, cables, logging tools, stems and so on. Downhole tool manufactured by OOO NPP RosTEKtechnologii allowed to successfully perform all fishing operations. Currently OOO NPP RosTEKtechnologii cooperate with OOO Gazprom podzemremont Urengoi, OOO Gazprom podzemremont Orenburg, OAO Surgutneftegas and OOO Integra-Service in the field of development and delivery of downhole equipment intended for well workover operations. Around 2500 tools of 34 designations have been delivered to our customers since 2008.
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P W qPM z D.V. Zinin, OAO NPO Burenie Long-length flush-joint pipe. Obvious advantages of coiled tubing. Coiled tubing units. Complex of downhole and backup tools. More than 40 kinds of tools were developed and tested. OAO NPO Burenie is looking to cooperate with. Development of new equipment and tools. Upgrading of machinery and downhole equipment utilization technologies.
M q M PM W z K.V. Burdin, Schlumberger ACTive* Technologies family is based on utilization of fiber-optic cable, which is situated within the standard coiled tubing (CT), for real-time transmission of bottomhole data to the surface. Fiber-optic cable is situated within a tube of 7/10-in. diameter, which is resistant to acids and other aggressive media. In comparison with cable, which is often used for well logging operations with CT utilization, ACTive* technology on the basis of fiber-optic cable is 20 times lighter. It is also corrosionresistant and can operate at temperatures up to 300 °F. Surface-mounted reading system that does not interfere with the process of injection and has a high density of real-time bottomhole data acquisition allows ACTive* monitoring of wells and treatments. It consists of the following elements: · Communication with bottomhole with the help of fiber-optic cables · Compensated neutron logging (CNL) (BHP, BHT and CCL) · DTS (distributed temperature sensing) · Surface-mounted electronics and software By means of fiber-optic cable ACTive* system transmits the following bottomhole data: • depth (the parameter is obtained using casing-collar locator (CCL)); • CT internal pressure at the bottomhole; • bottomhole pressure (BHP); • bottomhole temperature (BHT). Integrated services allow substantially reducing of operations time. Today the family of ACTive* technological services includes almost all types of CT services: 31
• ACTive Perforation • ACTive Flushing out • ACTive Bottomhole treatment • ACTive Sealing • ACTive Development • ACTive Profiling For the first time the family of ACTive* services allows real-time monitoring of wells and operations with CT utilization and provides the possibility of optimizing current and subsequent well operations.
M W M M R.K. Stanley, ItRobotics, IOS-PCI, and Coiled Tube Resource Management Hall effect sensors are used to measure the magnetic flux leakages (MFL) Bx (axial field) and Br (radial field). A second sensor set measure Bx for wall thickness measurement. Eddy current lift of measurement sensors are used to determine diameter and for the ovality computation. • Round-bottomed pits with maximal depth of 0.018-in. or 8.5% of specified wall; • MFL signals of a row of pits in the OD of stored pipe. The research performed at the University of Tulsa has shown that OD surface round-bottomed pitting that is less than 10% of the specified wall thickness deep does not have a serious effect on the fatigue life of the tubing. Used String: • Acid pitting, shallow gouges and some wall loss found in the bottom of the string; • Gouge MFL breaking threshold and the magnetic noise from the seam weld. We recommended removal of the bottom of the string because of the acid damage and corrosive wall loss. In cases where acid is run through CT strings, it is also essential to neutralize the acid immediately with an alkaline solution. Otherwise the acid will congregate in small puddles at the bottom of each wrap of the string, and cause severe pitting at these locations. Besides, in the report one can see the main characteristics of FlexorTU fatigue model software. Input parameters are diameter, wall thickness, grade, pressure, real diameter, guide-arch radius. These data permit the program to calculate the cycles on a fatigue machine, or the trips into a well, as the case may be. An inspector can then enter defect length, width and depth in the upper right of the screen, and immediately compute the effect of that defect on the fatigue life of the tubing at that point. Finally, the inspector can compute the effect of removing the defect by sanding. The model is based upon statistical analyses of real data taken on fatigue machines at the University of Tulsa, and elsewhere. Both unflawed and flawed samples were used. 32
P M k P P A.G. Molchanov, S.V. Romanenko, A.A. Klimenchekov, Gubkin Russian State University of Oil and Gas During the process of drilling or well workover coiled tubing string is exposed to complex influence of different forces. On practice the most dangerous section (from the point of view of tubing durability and lifetime) is the section between a reel and injector head. In this section the tubing bends and is exposed to significant plastic yields and influence of internal pressure at the same time. It is typical that the value of this pressure affects (decreases) the tubing lifetime in a substantial way. Nowadays in order to determine coiled tubing lifetime different empirical methods are used. Manufacturers perform fatigue tests under various external conditions, on the basis of which it is possible to make all necessary calculations. Among the advantages of this method one can find a high confidence of obtained results. The main disadvantage of this technique is that it is necessary to make full-scale specimens. Under conditions of batch production of coiled tubing manufacturing of specimens is not a difficult task. But if there is a need in exploration works (for example, selection of chemical composition of tubing metal), the cost and the duration of manufacturing process can significantly increase. The most optimal method of calculation of coiled tubing string estimated lifetime is analytical calculation on the basis of fatigue tension-compression tests of standard specimens with allowance for the stress state. Such practice is widely used for calculation of lifetime of details, load on which periodically changes and causes strain with magnitude not exceeding elastic limit. Fatigue strength that forms the basis of such calculations is determined almost for all grades of materials, which are used in mechanical engineering. In the case of coiled tubing strings, material of which is exposed to strain with magnitude exceeding yield limit, such database is missing. For calculation of coiled tubing lifetime it is necessary to perform analysis of stress-strain state that provides a transfer from three-dimensional stress state to monoaxial state, which is, in its turn, characterized by the magnitude of equivalent strains and stresses. It is also necessary to obtain experimental data that specify low cycle fatigue life beyond the elastic limit. During the coiled tubing reel on/off there appear stresses σа (ε), which are caused by the cyclic load of the tubing when it envelopes a reel and a guiding arc, and stresses σm (p) caused by the internal pressure. It is typical that stresses caused by the tubing bending act during the hard loading cycle, which is characterized by the strain regulation. Stresses caused by the internal pressure act during the soft loading cycle. Performed investigations showed that neither of existing dependencies of 33
plasticity theory can be used since there is a combination of plastic and elastic strains. It was established that the calculation of equivalent state of specimen, which simulate the tubing material, should be made on the basis of strains calculation. Taking Menson investigation as a basis it is possible to determine the influence of desired dependency. However, as opposed to the accepted statements one should use the value of secant modulus of elasticity, which characterizes the strain process beyond the yield limit. Magnitudes of equivalent strains, which a specimen being under conditions of monoaxial tension should withstand, after N loading cycles followed by the specimen failure will satisfy the equation ε
a equiv
= 77,6 N-0,79 +
σ
-1
(1-σm/σ vr) N01/m N-1/m /Е sec(εa equiv ) К Е,
where N – the number of cycles till specimen failure; N0 – base number of cycles, which corresponds to the value of fatigue limit σ-1; Еsec(ε∑) – secant modulus of elasticity that depends on the strains εa equiv ,which appear when the tubing envelopes a reel and a guiding arc; σm (p) – stresses caused by the internal pressure, m – exponent of power that characterizes material fatigue properties. Obtained dependency allows determination of equivalent strains that should be created during material specimens testing at a given stress state of a specimen. Comparison of the results of specimens testing at monoaxial stress state with testing parameters determined by the above-mentioned formula and the results of tubing full-scale tests showed that discrepancy did not exceed 7-9%. Thus it is possible to perform fatigue tests of specimens, simulating not only the values of plastic strains caused by the tubing bending but also the ones caused by the internal pressure influence.
34
HE LS F PARCPAS В. Baker Hughes
Andrey Smarovozov
В. Baker Hughes
Vitaly Vidavsky
Baker Oil Tools Distributor Ltd.
Sergey Lisov
Basheft-Geostroy
Sergey Goryuhin
Bashneft
Damir Muhametshin
Bashneft Dobycha
Oleg Serdukov
Belorusneft
Mikhail Halai
Belorusneft
Yuriy Butov
Belorusneft
Nikolay Demyanenko
Bico Drilling Tools
Michael Philpot
Blagodarov Oil
Rinat Xuzin
Burenie
Dmitry Zinin
Catobneft
Alexander Davydov
Catobneft
Dudnikov Andrey
Coiled Tube Resource Management
Roderic K Stanley
Coiled Tubing Service
Almas Khamidullin
Coiled Tubing Times
Sergey Torpachev
Coiled Tubing Times
Halina Bulyka
Coiled Tubing Times
Olga Gabdulkhakova
CTTDC
Vladimir Shurinov
CTTDC
Boris Vydrik
CTTDC
Leanid Hruzdzilovich
CWS International
Sergey Grunin
Eriell Corporation s.r.o.
Jamolidin Rahmonov
Foremost Industries LP
James Frederick Chernyk
Foremost Industries LP
Maria Kursakova
Foremost Industries LP
Irina Matkovskaya
Foremost Industries LP
Tatiana Shubaeva
Gazprom Dobycha Astrakhan
Igor Polyakov 35
Gazprom Dobycha Astrakhan
Vyacheslav Vasiliev
Gazprom Neft
Andrei Demenkov
Gazprom Neft-Vostok
Mikhail Dviborodchin
Global Tubing
Jacques Attie
Global Tubing
C. Robert Bunch
Global Tubing
H.B. Luft
Haihua Industry Group
Li Jiavchen
Haihua Industry Group
Yang Ponglin
Haihua Industry Group
Yu Han
Haihua Industry Group
Xlian Linyun
Haihua Industry Group
Zhang Chunfeng
ICoTA
Eric Boeke
ICoTA
Allison Babin
Immertechnik
Grigoriy Zhuravlev
Institute of Industrial Chemistry, Gubkin Russian State University of Oil and Gas
Lubov Magadova
Institute of Industrial Chemistry, Gubkin Russian State University of Oil and Gas
Luchia Davletshina
Institute of Industrial Chemistry, Gubkin Russian State University of Oil and Gas
Oxana Efanova
Institute of Industrial Chemistry, Gubkin Russian State University of Oil and Gas
Kira Poteshkina
Institute of Industrial Chemistry, Gubkin Russian State University of Oil and Gas
Alexander Molchanov
Kogalymnefteprogress
Ivan Kuzmin
Maximum Service
Alexei Antropov
Ministry of Industry and Trade of the Russian Federation
Leonid Kondratov
National Oilwell Varco
Alexey Anopov
National Oilwell Varco
Andy Jenkinson
NOV Fidmash
Alena Lapatsentava
NOV Fidmash
Sergey Yurutkin
NOV Fidmash
Andrei Verigo
NOV Fidmash
Sergey Kablash
36
Novinka
Ivan Pirch
Novinka
Sergei Atrushkevich
Novinka
Pavel Laktionov
OFTC
Vyacheslav Gorobiychenko
OFTC
Viktor Ternavshenko
Oil and Gas Eurasia
Marina Alyoshina
Oil and Gas Technologies
Natalie Kutasova
Oil and Gas Vertical
Tatiana Adyakova
OMK
Anna Hasanova
OMK Stal
Viacheslav Afanacev
Packer
Elmir Kabirov
Packer
Alexander Lukin
Poltava Oil and Gas Company
Aleksandr Kryvenko
Poltava Oil and Gas Company
Vladimir Taran
Region
Yuriy Kitsenko
Rosen Europe B.V.
Rutger Van Kampen
Rosen Russia
Igor Bogatyrev
Rosen Swiss A.G.
Marc Seeger
Rosneft
Viktor Bochkarev
RosTEKtehnologii
Yury Shtakhov
Schlumberger
Aleksandr Sorokin
Schlumberger
Konstantin Burdin
Schlumberger
Konstantin Basanov
Schlumberger
Igor Chen
SERVAgroup
Ray Backer
SERVAgroup
Doug Reder
SMM
Alexey Smirnov
SMM
Vyacheslav Savasteev
outh-Russian State Technical University (Novocherkassk Polytechnical Institute)
Alexander Tretyak
Surgutneftegas
Andrey Popov
Surgutneftegas
Sergey Gabrelyan
37
