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Abstract
표목차
그림목차
칼라
목차
제1장 서론 13
제2장 'K' 가스전의 저류층 특성 16
제1절 가스전 개요 16
제2절 저류층 특성 및 유체물성 18
제3장 'K' 가스전의 개발 및 생산 22
제1절 가스전의 개발 개요 22
제2절 가스-컨덴세이트 유동 23
1. 가스-컨덴세이트 유동체계 23
2. 단상 가스유동 근사법 25
제3절 생산성 및 생산시스템 분석 29
1. 가스전 및 가스정 산출능력 29
2. 생산시스템 분석 37
제4절 포기압력 및 회수율 예측 51
1. 포기압력(폐기압력) 52
2. 회수율 및 가채매장량 예측 55
제5절 향후 생산추이 예측 58
제4장 가스 생산 및 처리 시설 61
제1절 개요 61
제2절 가스 처리시스템 설계 63
제3절 가스 처리시설 67
1. 플랫폼 (platform) 시설 68
2. 육상 인수기지 시설 78
제4절 가스하이드레이트 생성 방지 84
제5장 파이프라인 수송 88
제1절 가스-컨덴세이트 2상 파이프라인 유동해석모델 88
1. 서론 88
2. 2상 비정상 유동 방정식 89
3. 2상 비정상 유동모델 개발 111
제2절 'K' 가스전의 수송 파이프라인 분석 127
1. 파이프라인의 용량 및 수송능력 분석 128
2. 부식속도비(EVR) 분석 138
제6장 결론 143
참고문헌 145
판권지 148
Table 2-1. Reservoir and well conditions 18
Table 2-2. Gas flow characterization 19
Table 2-3. Condensate flow characterization 19
Table 2-4. Recombined fluid composition of separator gas and condensate 20
Table 2-5. Reserve and DCQ of 'K' gas field 21
Table 2-6. Production of each case and transmission 21
Table 3-1. Producing GLR of 'K' gas field 25
Table 3-2. Fluid properties of gas-condensate system 28
Table 3-3. Results of welltest analysis 35
Table 3-4. Coefficients of several horizontal flow equations 39
Table 3-5. Definition of friction factor in horizontal equations 39
Table 3-6. Minimum gas-producing rate for continuous liquid removal in 'K' gas field. 50
Table 3-7. Estimate of recovery factor and recoverable reserves 57
Table 4-1. Fluid flow rate of each case. 61
Table 5-1. Coefficients for K-value 102
Table 5-2. Parachors for pure substances 111
Table 5-3. Conditions of transmission pipeline 127
Table 5-4. Results of hydraulic analysis of pipeline 142
Figure 2-1. Temperature and sound velocity profile in 'K' gas field 17
Figure 2-2. Phase diagram of reservoir fluid in 'K' gas field 21
Figure 3-1. Pressure-Temperature diagram, classification of hydrocarbon system. 24
Figure 3-2. (a)Back-pressure analysis and (b)IPR curve 30
Figure 3-3. Inflow performance curve of a well in 'K' gas field (AOF=56.5 MMscfd) 36
Figure 3-4. Bottomhole solution 44
Figure 3-5. Tubing performance relation curves (Pwh=2000 psi) 45
Figure 3-6. Tubing performance relation curves (Pwh=1500 psi) 46
Figure 3-7. Tubing performance relation curves (Pwh=1000 psi) 46
Figure 3-8. Tubing performance relation curves(cureves) (Pwh=500 psi) 47
Figure 3-9. Minimum volumetric flow rate for continuous liquid removal (tubing ID=3.958″ ) 51
Figure 3-10. Relation of wellhead pressure, Pwh, with reservoir pressure, Pr, at various flow rates in IPR and TPR (solid : Pr, dotted : flowing BHP, Pwf) 53
Figure 3-11. Determination of abandonment pressure (Qmin=1 MMscfd, OD4.5″ × ID3.958″ tubing) 55
Figure 3-12. Performance prediction (DCQ : 5 MMscfd/well) 60
Figure 4-1. Gas process units on the offshore in 'K' field. 62
Figure 4-2. Gas process flow diagram on the platform in 'K' field. 65
Figure 4-3. Gas process flow diagram on the onshore in 'K' field. 66
Figure 4-4. Typical vertical oil and gas separator with mist extractor (From Society of Petroleum Engineers of AIME) 70
Figure 4-5. High pressure horizontal oil and gas separator (From Courtes Black, Sivals, and Bryson, Inc.) 71
Figure 4-6. Constant used in gas capacity equation (after Arnold et al.). 73
Figure 4-7. Vertical three-phase separator schematic (after Arnold et al). 74
Figure 4-8. Produced water treating system (after Arnold et al.). 77
Figure 4-9. Condensate stabilization system (after Arnold et al.). 79
Figure 4-10. Cold-feed distillation tower of condensate stabilization system (after Arnold et al.) 80
Figure 4-11. McKetta-Wehe pressure-temperature correlation (From Gas Processors Suppliers Association, Eng. Data Book, 10th Ed.) 83
Figure 4-12. Typical glycol contactor in which gas and liquid are in counter-current flow (after Arnold et al). 84
Figure 4-13. Calculated results for the hydrate forming conditions for 'K' gas field 87
Figure 5-1. Pipeline deliverability : single-phase gas only (horizontal pipeline assumed) 129
Figure 5-2. Pipeline deliverability : single-phase gas only(Q=10 MMscfd w/ elevation) 130
Figure 5-3. Pipeline deliverability : single-phase gas only(Q=20 MMscfd w/ elevation) 130
Figure 5-4. Pipeline deliverability : single-phase gas only(Q=30 MMscfd w/ elevation) 131
Figure 5-5. Pipeline deliverability : condensate only (w/ elevation) 132
Figure 5-6. Pipeline deliverability : gas and condensate (Q=10 MMscfd) 133
Figure 5-7. Pipeline deliverability : gas and condensate (Q=20 MMscfd) 134
Figure 5-8. Pipeline deliverability : gas and condensate (Q=30 MMscfd) 134
Figure 5-9. Pipeline deliverability : gas and condensate (Pipe ID=8.001″ ) 135
Figure 5-10. Pipeline liquid holdup : gas and condensate (Pipe ID=8.001″ ) 136
Figure 5-11. Pipeline flow regime : gas and condensate (Pipe ID=8.001″ ) 138
Figure 5-12. Erosional velocity ratio profile : gas only 140
Figure 5-13. Erosional velocity ratio profile : condensate only 141
Figure 5-14. Erosional velocity ratio profile : gas and condensate 141