KAZAKHSTAN UPSTREAM OIL AND GAS technology and R&d ...

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88 The ability to carry out complex reservoir modelling will be very important. So will be the introduction of EOR best practices from other parts of the world and the adaptation of the various technologies to match the conditions found in individual fields. Kazakhstan Upstream oil & gas technology and R&D roadmap
4.2 Field management: optimised recovery including IOR/EOR Challenge commentary Maximising the production and ultimate recovery of oil and gas from existing assets is a constant challenge for operators all around the world. The conditions in Kazakhstan – unusually complex reservoirs, high temperatures and pressures, high H 2 S levels and arctic weather conditions – all combine to pose particularly difficult field management problems for even the leading operators. Waterflooding for improved oil recovery (IOR) is used extensively in Kazakhstan. However, matching the properties of the injection stream with those of the hydrocarbons present in the reservoir and the characteristics of the rock matrix is not easy. Consequently, benefits are often limited and field performance may even decline as a result of this treatment. Selecting the best enhanced oil recovery (EOR) technique, or combination of IOR and EOR, is even more fraught and the economics even more likely to prove unsatisfactory. The challenge is to better understand (via data capture, analysis and modelling) the reservoirs and be able to predict more accurately what will happen when water, chemicals, gas or heat are used to enhance hydrocarbon recovery. EOR is known to be largely ineffective in tight reservoirs, which require stimulation by, for example, fracturing, acid treatment or re-perforation. The challenge here surrounds the modelling, selection, application and monitoring of the chosen stimulation technique in tight carbonate reservoirs with few natural fractures, such as the Korolev field. A third challenge is specifically related to the understanding and management of coning and water and gas breakthrough under different depletion profiles, vital to achieving high recovery factors with fewer wells. Problems are particularly acute during the final stages of production, when formation pressure and flow rates fall and water influx increases. Karashaganak, Kenkiyak, Zhanazhol and Alibekmola fields have all experienced problems along these lines. VALUE CHALLENGE (elements) EOR techniques Improved well productivity from tight reservoirs 4.2.6 4.2.7 4.2.8 4.2.10 4.2.1 4.2.5 4.2.9 4.2.2 4.2.3 4.2.4 4.2.11 TECHNOLOGY SOLUTIONS 4.2.2 Advanced waterflooding & EOR 4.2.3 EOR gas injection 4.2.4 EOR modelling 4.2.11 Optimised field management 4.2.1 Well stimulation 4.2.5 Water based fracture fluid systems 4.2.6 Fracture monitoring & control ATTRACTIVENESS 4.2.7 ‘In-well monitoring’ for observing reservoir dynamics 4.2.8 ‘In-well monitoring’ using wireline tools (for integrity & water content) 4.2.9 Reservoir monitoring with geo-chemistry & tracers 4.2.10 Well (in)flow control 89 Management of coning, water & gas breakthrough Kazakhstan Upstream oil & gas technology and R&D roadmap
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Kazakhstan upstream oil and gas tec
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A pragmatic steer for technology de
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Kazakhstan Upstream oil and gas tec
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KazNTU Izim Dussembayev, Institute
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Technology solutions Over 230 possi
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It would be realistic to expect the
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Learning and skills development in
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THE INTRODUCTION THE FUNDAMENTALS F
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Roadmap development Project objecti
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Stage 3 - the way forward The work
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The causes of the challenges facing
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4.2 Field Management−Optimise Rec
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VALUE TTA 1 RESERVOIR CHARACTERISAT
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The technology solutions and their
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Introducing the topic maps Introduc
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1. Reservoir characterisation Reser
Page 37 and 38: 1.1 Seismic data acquisition and pr
Page 39 and 40: NOW 2015 2020 2025 TECHNOLOGIES AND
Page 41 and 42: 1.2 Reservoir description - geology
Page 43 and 44: NOW 2015 2020 2025 Basin modelling
Page 45 and 46: 1.3 Well logging and in-well monito
Page 47 and 48: NOW 2015 2020 2025 Wireline formati
Page 49 and 50: 1.4 Core analysis and data interpre
Page 53 and 54: 1.5 Fluid property analysis Challen
Page 57 and 58: 2. Field equipment Designing and bu
Page 59 and 60: 2.1 Corrosion plus equipment and ma
Page 61 and 62: NOW 2015 2020 2025 Corrosion resist
Page 63 and 64: 2.2 Operating in the ice and during
Page 67 and 68: 2.3 Management of sulphur Challenge
Page 69 and 70: NOW 2015 2020 2025 Sulphur separati
Page 71 and 72: 3. Fluid flow and processing Flow a
Page 73 and 74: 3.1 Flow assurance and sand control
Page 75 and 76: NOW 2015 2020 2025 3D flow modellin
Page 77 and 78: 3.2 Water management Challenge comm
Page 79 and 80: NOW 2015 2020 2025 Diagnostic evalu
Page 81 and 82: 4. Wells and field management The m
Page 83 and 84: 4.1 Drilling and well costs Challen
Page 85 and 86: As for the second challenge, most o
Page 87: NOW 2015 2020 2025 Casing and liner
Page 91 and 92: NOW 2015 2020 2025 Well stimulation
Page 93 and 94: 5. HSE and operations The oil indus
Page 95 and 96: 5.1 Emergency response and disaster
Page 97 and 98: NOW 2015 2020 2025 Quantitative ris
Page 99 and 100: 5.2 Operational HSE risk reduction
Page 101 and 102: NOW 2015 2020 2025 Breathing appara
Page 103 and 104: 5.3 Environmental impact Challenge
Page 105 and 106: NOW 2015 2020 2025 Chemical and mem
Page 107 and 108: Technology and R&D n R&D funding ne
Page 109 and 110: GOVERNANCE Process platform: govern
Page 111 and 112: Capabilities across the 15 prime ch
Page 113 and 114: GOVERNANCE NOW 2015 2020 2025 Proce
Page 115 and 116: INDUSTRY ENABLERS SKILLS R&D GOVERN
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