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

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4.2 Field management: optimised recovery including IOR/EOR 90 Solutions commentary The ultimate goal in this area is to increase oil production from existing assets through improvements in reservoir engineering. Stimulation techniques are intended to restore well productivity that has been reduced by bottom-hole zone damage, the result of poor well packing, asphaltene/resin/ paraffin deposits, scaling, etc. The objective is to deal with these problems and restore initial production and water intake capacity. Techniques include treatment with hot water, condensate, hydrochloric acid, steam, surfactants etc. To select the optimal chemical for bottom-hole treatment, a core analysis must be carried out and the bottom-hole zone modelled to test the intended treatment. Based on laboratory results and the modeling work, recommendations can be made for pilot testing, and thereafter a decision made for a wider application. Fracturing plays an important role in improving productivity. The efficiency of fracturing (i.e., the depth of fracturing, filling of fractures and duration of the effect) is dependent on the selection of the most efficient fracturing fluid. A combination of hydrofracturing, acid treatment and surfactants is usual to achieve the optimum effect. Selecting appropriate wells (with no defects in the casing) is also important – pilot testing should be carried out on selected wells. Hydrofracturing monitoring, analysis and management of all field operations are mandatory processes. They enable the efficiency of the technology to be determined, the cost of the job to be estimated and deliver G&G studies on estimated ultimate recovery and reservoir behaviour. Based on fracturing monitoring and analysis, the technical and economic feasibility of fracturing the asset can also be determined. EOR modeling requires input data from laboratory core analysis, deep oil samples, samples from drill sumps (asphaltene/resin/ paraffin deposits, scaling, etc.), G&G and other activities. Based on the results, a model of the bottomhole zone can be prepared and different EOR options assessed. The selected technique should be tested at the selected location and based on the results a specific EOR technique recommended for deployment. Problems or challenges encountered may vary, for example asphaltene/resin/paraffin deposits, scaling, incomplete perforation of pay zone, plugged drill sump, etc. All of these generally result in well production and water intake capacity decrease. To address these challenges, well intervention will be required, including bottom-hole zone treatment by various fluids, chemicals, re-perforation and additional perforation, drilling (restoring) the drill sump, etc. The most efficient waterflooding, reservoir pressure maintenance or EOR technique must be selected based on laboratory analysis, reservoir and bottom-hole zone models and pilot tests. Advanced waterflooding is about changing the reservoir pressure maintenance techniques, testing different systems and elements subject to G&G features and heterogeneity. EOR is based on laboratory analysis, modelling, pilot testing and reviewing the various advanced technologies, including physical, chemical and thermal techniques. EOR gas injection is a very promising technology, widely deployed in fields around the world. Gases used include associated gas, CO 2 , nitrogen, etc. Technology and chemical have to be selected based on the core analysis, G&G studies, reservoir and dynamic models, pilot testing. Following the results of all tests, and if positive technical and economic factors are achieved, recommendations will be generated for specific injection techniques or combination of techniques. Kazakhstan Upstream oil & gas technology and R&D roadmap
NOW 2015 2020 2025 Well stimulation Water-based fracture fluid systems G A P G A P • Implement electrical effecting stimulation • Optimised drilling fluids Reduce well workover and intervention time TECHNOLOGIES AND GAPS Fracture monitoring and control EOR modelling Well (in)flow control Advanced waterflooding and EOR EOR gas injection G A P G A P G A P G A P Identify field management best practices Multi-zone completion and isolation tools Limited smart wells (ICVs, DTS, etc.) Reservoir “type” onshore EOR field trials Field management best practices Improved infield gathering systems Smart wells base option in new, sour fields Extensive pertinent EOR operations Optimised (real-time) field management Smart wells base option in all fields Depleted fields equipped for EOR 91 Reservoir surveillance capabilities 1.1 Road map INDUSTRY • Local production of chemicals • Geo-chemical tracer studies: JV with operators • Fluid production capability • Materials and equipment to support new technologies R&D • Establish annual cycle: R&D and operator/ISC interaction • EOR screening capability. • Longevity of fibre optics. • Mud reservoir interaction • Quantitative DTS modelling • New sensors for well performance monitoring SKILLS • Determine (I)OR and local industry skills requirements versus supply from universities ENABLERS • Establish R&D governance 4.2 Field management: optimised recovery including IOR/EOR 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
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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 and 88: NOW 2015 2020 2025 Casing and liner
Page 89: 4.2 Field management: optimised rec
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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