臺灣博碩士論文加值系統

本研究目的是以物質平衡法理論推導二氧化碳封存於天然氣氣層之解析方程式通解，以及無因次注儲典型曲線作為二氧化碳封存量估算之用，並透過數值模擬法進行驗證比較，現場案例研究，建立已耗竭凝結油氣層之數值模型，透過歷史調諧以及二氧化碳注儲操作，進行解析法與數值法之結果比較。
本研究推導出天然氣層在有無水驅機制之二氧化碳封存量解析方程式通解，適用於乾氣、濕氣以及凝結油氣層；亦可將注儲解析方程式轉換成注儲典型曲線做為二氧化碳封存封存量估算之用，預期做為二氧化碳封存於舊天然氣層之場址篩選評估之用。
凝結油氣層生產及注儲二氧化碳行為之p/z2p隨壓力變化中，生產期間之偏差因子會隨著壓力下降而變小，當注入二氧化碳時，隨著二氧化碳與天然氣混合，混合之偏差因子會緩慢的上升，其趨勢會逐漸接近於純二氧化碳之偏差因子，整體而言會比生產期間之天然氣偏差因子的值還小。同樣地，觀察p/z曲線隨壓力變化，比較相同壓力下之p/z值，二氧化碳注入期間之p/z值比天然氣生產期間變化來得低，此現象代表著二氧化碳注入於地層之中，可以封存的量會比天然氣產量還要來得多。
比較乾氣層及凝結油氣層在相同生產及注儲操作下（一樣的注產氣比操作），凝結油氣層之氣體採收率會略低於乾氣層，若直接使用乾氣層之典型曲線進行凝結油氣層之二氧化碳封存量估算會產生誤差；故在凝結油氣層之二氧化碳封存能力估算上，必須考慮整體的油氣產量（天然氣及凝結油），方能達到精確的封存量估算，也顯示出凝結油氣層相對於乾氣層之二氧化碳封存潛能優勢。針對所推導之凝結油氣層物質平衡法進行變動地層原始壓力及流體成分性質(貧氣及富氣凝結油氣層)之敏感度分析結果中，都得到不同的預測及驗證結果。
本研究所推導二氧化碳注儲分析曲線應用於台灣Y凝結油氣層進行歷史調諧及二氧化碳注儲模擬研究，p/z作圖法分析得初始氣體埋藏量為45,540 MMSCF，其氣體採收率為0.72，模擬過程中注入48,870 MMSCF（2.58百萬噸）二氧化碳，其p/z比值（PZR）為1.275（地層壓力回復至4,850 psi）；而原始油氣當量（DTE）為1.088，生產油氣當量（DPE）為1.028，代入典型曲線方程式可得預測之注產氣比為1.443。

The purpose of this study is to develop general analytical equations and type curves for estimating the CO2 storage capacity of natural gas reservoirs. Numerical simulations for different types of natural gas reservoirs were done to study the CO2 storage capacity and to validate the developed analytical solutions. A simulation case study is implemented to calculate the CO2 storage capacity in a target storage site, and the simulated result of CO2 storage capacity is compared by that from the derived p/zmixCO2 plot.
This study successfully derives general analytical equations and type curves. This general solution is capable of analytically calculating CO2 storage capacity of dry-gas, wet-gas, and gas-condensate reservoirs. Furthermore, this method is useful for site screening of CO2 storage in depleted natural gas reservoirs.
In the gas-production stage, the z-factor of natural gas (z) decreased with the decreasing formation pressure. However, in the CO2-injection stage, the z-factor of mixed gases (zmixCO2) increased when the formation pressure was recovering. Generally, the value of the zmixCO2 was smaller than that of the z-factor of natural gas under a specific formation pressure. If the initial formation pressure (pi) is considered, the value of the pi/zmixCO2 when CO2 injection finished will be higher than that of the pi/zi of the gas-condensate reservoir. More CO2 can be stored in a gas-condensate reservoir than the amount of natural gas produced.
Numerical simulations for different types of gas reservoirs were used to study their CO2 storage capacity. Additionally, the comparisons of CO2 storage capacity estimates showed that the outcomes of analytical solutions and numerical simulation were similar. The accuracy of the derived general equation was validated.
For the case study, the target site was the Y gas-condensate reservoir located in the Y gas field in northwestern Taiwan. The original gas in place (OGIP) of the Y gas-condensate reservoir was about 45,540 million standard cubic feet (MMSCF) which was estimated from the p/z plot based on the measured productions, formation pressures, and corresponding z-factors. The Y gas-condensate reservoir is a nearly depleted reservoir with a very weak water drive.
Geological and numerical models of the Y gas-condensate reservoir were constructed in this study. Before the simulated CO2 injection started, the numerical model was well tuned using history matching. The simulations of CO2 injection showed that the total CO2 injected was 48,870 MMSCF (2.58 million tons) when the formation pressure was recovered to the initial pressure of 4,850 psi.
The injection/production ratio (IPR) calculated by the derived equation was 1.44 based on the estimates of the ratio of initial p/z and injected p/zmixCO2 (PZR), dimensionless total equivalent gas ratio (DTE), and dimensionless produced equivalent gas ratio (PEG) of 1.275, 1.088, and 1.028, respectively. The value of IPR from analytical method was identical to that derived using the numerical method.

Abstract I
中文摘要 II
誌謝 IV
Contents V
List of Tables VII
List of Figures VIII
Nomenclature XII
Chapter 1 Introduction 1
1.1 Greenhouse effect and climate change 1
1.2 CO2 geosequestration 6
1.3 CO2 storage in depleted gas-condensate reservoirs 9
1.4 Motivation 13
1.5 Purposes 14
1.6 Organization 14
Chapter 2 Literature Review 16
2.1 Material balance equations in natural gas reservoirs 16
2.2 PVT properties calculation of gas-condensate reservoirs 22
2.3 CO2 storage and injection in depleted natural gas reservoir 25
2.4 Summary of literature review 34
Chapter 3 Theoretical background 35
3.1 Analytical solutions of p/z plot method 35
3.1.1 General solution of p/z plot of natural gas reservoir 35
3.1.2 Injecting general equations of p/zmix plot 38
3.1.3 Dimensionless injection type curve equations 40
3.1.4 Cumulative water influx 41
3.2 Numerical method of simulations 42
3.2.1 Equation of state (EOS) of Fluid 42
3.2.2 Numerical simulation 45
Chapter 4 Results and Discussion 48
4.1 Validation of p/z analytical equations during depletion 48
4.1.1 Validation of the p/z plot method in dry gas model 51
4.1.2 Validation of the p/z2p plot method in a gas-condensate model 54
4.1.3 Sensitivity analysis of the p/z2p plot method in the gas-condensate model 56
4.2 Validation of p/z analytical equations during CO2 injection 60
4.2.1 Validation of CO2 injection type curve for dry-gas reservoirs 60
4.2.2 Validation of CO2 injection type curve on gas-condensate reservoirs 64
Chapter 5 Case study 73
5.1 Geological, engineering, and fluid experimental data 73
5.2 EOS tuning using regression analysis 80
5.3 Numerical model construction and history matching 85
5.4 CO2 injection and type curve estimation 95
Chapter 6 Conclusions and Suggestions 100
6.1 Conclusions 100
6.2 Suggestions 102
References 103

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