本文選題：壓力-應(yīng)力耦合 + 超壓流體泄放��； 參考：《中國地質(zhì)大學(xué)》2016年博士論文

【摘要】：鶯歌海盆地位于華南板塊、巽他板塊、南海海盆的三角連接帶,具有豐富的油氣資源儲(chǔ)量。高溫高壓嚴(yán)重制約著鶯歌海盆地的油氣勘探成功率,而探尋盆地內(nèi)超壓流體泄放機(jī)制、過程及伴生油氣成藏效應(yīng)則可科學(xué)、有效地規(guī)避勘探風(fēng)險(xiǎn)。本文利用鶯歌海盆地東方區(qū)豐富的鉆、測(cè)井資料,通過揭示原位壓力、應(yīng)力狀態(tài),探究壓力-應(yīng)力關(guān)聯(lián)性,論證了超壓流體泄放機(jī)制；結(jié)合鶯歌海盆地東方區(qū)三維地震反射數(shù)據(jù)體,宏觀識(shí)別、歸納超壓流體泄放構(gòu)造(結(jié)構(gòu))特征、分布規(guī)律,恢復(fù)了超壓流體泄放的時(shí)空過程;基于東方區(qū)不同壓力-應(yīng)力狀態(tài)油氣藏的氣體地球化學(xué)、巖石或礦物學(xué)微觀對(duì)比,揭示了東方區(qū)超壓流體泄放過程伴生的油氣成藏效應(yīng)。取得的主要認(rèn)識(shí)如下：1、走滑應(yīng)力體制下,東方區(qū)超壓封存能力較強(qiáng),中新統(tǒng)普遍存在強(qiáng)超壓。垂向主應(yīng)力均大于相應(yīng)深度的最小主應(yīng)力量級(jí),但小于或接近相應(yīng)深度的WNW-ESE向最大水平主應(yīng)力量級(jí),整體處于走滑應(yīng)力體制。近E-W向水平擠壓受控于巽他地塊、華南板塊的水平位移,時(shí)間上起源于中新世早期。東方區(qū)中新統(tǒng)壓力梯度普遍高于17 MPa/km,部分構(gòu)造高點(diǎn)的壓力處于接近或略微超過相應(yīng)深度最小主應(yīng)力(或最小水平主應(yīng)力)的臨界狀態(tài),具備水力裂縫形成的條件。東方區(qū)的區(qū)域壓力-應(yīng)力耦合系數(shù)為0.7,近似于南海西南部地區(qū)(約0.66),但顯著高于南海南部文萊近海區(qū)(0.58)。走滑擠壓應(yīng)力體制下東方區(qū)的超壓封存能力弱于走滑或逆沖擠壓更為顯著的南海南部俯沖帶,但仍強(qiáng)于具有理想伸展應(yīng)力體制的地區(qū)。2、東方區(qū)發(fā)育垂向管柱體和氣煙囪兩類超壓流體泄放構(gòu)造。西緣上斜坡區(qū)大量管柱體刺穿上中新統(tǒng),并終止于上新統(tǒng)底面；中央隆起高部位氣煙囪刺穿或終止于上新統(tǒng)。垂向流體泄放構(gòu)造的發(fā)育在時(shí)間上與中新統(tǒng)超壓的發(fā)育、烴源巖的生烴以及構(gòu)造活躍相耦合。垂向流體泄放構(gòu)造的時(shí)空差異分布,指示晚中新世超壓流體大規(guī)模向西緣上斜坡運(yùn)移,而上新世以來大規(guī)模向中央隆起高點(diǎn)匯聚。走滑擠壓作為外在觸發(fā)機(jī)制對(duì)東方區(qū)垂向泄放構(gòu)造的形成必不可少。一方面,擠壓強(qiáng)度的垂向差異,可導(dǎo)致深層二次增壓強(qiáng)(水平擠壓增壓),淺層二次增壓弱；另一方面,構(gòu)造擠壓導(dǎo)致的砂體超過約500 m的翹傾、抬升加速了深層強(qiáng)超壓流體向淺層高點(diǎn)的匯聚,形成的局部壓力-應(yīng)力耦合；二者的聯(lián)合作用足以擾動(dòng)淺層弱超壓的區(qū)域壓力-應(yīng)力耦合作用,形成水力破裂。3、東方區(qū)C1、C2氣田超壓油氣保存能力不同,系統(tǒng)開放程度差異,并導(dǎo)致氣體組分、碳同位素分異,上中新統(tǒng)砂巖成巖過程、礦物組分差異。①C1氣田超壓油氣保存能力小于6 MPa,甚至達(dá)到0,而C2氣田超壓油氣保存能力普遍高于約6MPa～7MPao C1、C2氣田超壓油氣保存能力不同,指示了系統(tǒng)開放程度差異。②C1、C2氣田具有相同的烴源巖,但是組分、同位素分析表明：C2氣田所有烴氣樣品的11個(gè)參數(shù)隨成熟度增加均一偏移；而C1氣田所有烴氣樣品的δ¨n-iC4相對(duì)于成熟度增加負(fù)偏特征顯著,其余10個(gè)參數(shù)隨成熟度增加一致正向偏移。C1氣田烴氣的δ13n-iC4負(fù)偏,違背了封閉熱解實(shí)驗(yàn)中丁烷同分異構(gòu)體在成熟度增加過程中nC4/iC4增大、813nC4和813iC4偏重、δ13nC4/513iC4增大的趨勢(shì),指示了高系統(tǒng)開放程度下烴氣散失的發(fā)生。高開放程度系統(tǒng)中烴源巖低熟熟階段生成氣體難以保存,而高熟烴氣或過熟無機(jī)二氧化碳相對(duì)富集；低開放程度(封閉)系統(tǒng)內(nèi),烴源巖不同成熟階段生成氣體均會(huì)被高效保存,但大量低成熟度階段烴氣、氮?dú)獾膬?yōu)先富集會(huì)較大程度地稀釋高熟烴氣或過熟無機(jī)二氧化碳。③C1、C2氣田上中新統(tǒng)砂體均來源于越東物源區(qū),經(jīng)歷相同的搬運(yùn)、沉積過程,但薄片統(tǒng)計(jì)或X衍射分析表明：C1氣田上中新統(tǒng)砂巖長石顆粒、綠泥石含量偏低,高嶺石、伊蒙混層偏高,富含鐵白云石膠結(jié)；C2氣田上中新統(tǒng)砂巖長石顆粒、綠泥石含量偏高,高嶺石、伊蒙混層含量偏低,富含方解石膠結(jié)。C1氣田上中新統(tǒng)砂巖長石顆粒、綠泥石含量低于C2氣田,指示了相對(duì)更強(qiáng)烈的溶蝕。綠泥石的溶蝕釋放大量Mg2+、Fe2+,有助于富Mg-Fe的碳酸鹽巖在C1氣田上中新統(tǒng)砂巖內(nèi)沉淀、膠結(jié)。C1氣田上中新統(tǒng)砂巖在強(qiáng)烈溶蝕下仍富集對(duì)K+非常敏感的伊蒙混層、高嶺石,表明溶蝕-沉淀過程中存在K+的流失。鹽水包裹體均一溫度介于110℃～170℃范圍時(shí),C1氣田上中新統(tǒng)砂巖內(nèi)鹵水鹽度低于C2氣田,也表明C1氣田上中新統(tǒng)砂巖鹵水中溶質(zhì)流失。高開放程度下鹵水泄放直接導(dǎo)致了C1氣田上中新統(tǒng)砂巖內(nèi)成巖過程中的物質(zhì)流失、溶蝕-沉淀物質(zhì)不均衡。盡管高開放程度下的鹵水泄放改善了C1氣田上中新統(tǒng)砂巖孔隙物性,但孔隙度僅提高1vo1%～4 vo1%,且物性改善時(shí)期不早于烴類充注期,因此,孔隙改善對(duì)油氣成藏的實(shí)質(zhì)性貢獻(xiàn)有限。
[Abstract]:Yinggehai basin is located in the Southern China plate, the Sunda plate and the triangular connection zone of the South China Sea basin, which has rich reserves of oil and gas. High temperature and high pressure seriously restricts the success rate of oil and gas exploration in Yinggehai basin, and the exploration of overpressure fluid drainage mechanism in the basin, process and associated oil and gas accumulation effect can be scientific and effective to avoid exploration risk. With the rich drilling and logging data in the Orient area of Yinggehai basin, Wen Li demonstrated the pressure and stress correlation in situ, explored the pressure stress correlation, demonstrated the overpressure fluid discharge mechanism, and combined with the 3D seismic reflection data in the Orient area of Yingge basin, the macroscopic recognition, the induction of overpressure fluid discharge structure (structure), distribution law and recovery. The space-time process of overpressure fluid drainage is carried out. Based on the gas geochemistry of the oil and gas reservoirs in different pressure stress states of the eastern region, the microcosmic comparison of rock and mineralogy reveals the associated oil and gas accumulation effect in the process of overpressure fluid discharge in the eastern region. The main understanding is as follows: 1, under the strike slip stress system, the ability of overpressure in the eastern region is stronger, There is a general strong overpressure in the middle Miocene. The vertical main stress is greater than the minimum main stress level of the corresponding depth, but the WNW-ESE to the maximum horizontal main strength level is less or closer to the corresponding depth, and the whole is in the strike slip stress system. The near E-W horizontal extrusion is controlled by the Sunda block, and the horizontal displacement of the Southern China plate is originated in the early Miocene. The pressure gradient of the middle Miocene in the eastern region is generally higher than that of 17 MPa/km, and the pressure of some structural high points is near or slightly above the minimum principal stress (or the minimum horizontal principal stress) at the corresponding depth, and has the condition of the formation of hydraulic fractures. The regional pressure stress coupling coefficient of the eastern region is 0.7, approximately in the southwest of the South China Sea (about 0.66). But it is significantly higher than the southern Brunei coastal area (0.58) in South China Sea. The overpressure sealing ability of the eastern region under the strike slip extrusion stress system is weaker than the southern subduction zone of the South China Sea, which is more significant than the strike slip or thrust extrusion. But it is still stronger than the.2 in the area with ideal extensional stress system, and two types of overpressure fluid discharge structures are developed in the vertical tube and gas chimney in the East. A large number of tubular columns in the upper slope of the west edge pierce the middle Miocene and terminate at the bottom of the upper Miocene; the high position gas chimneys of the central uplift pierce or terminate in the upper Miocene. The development of the vertical fluid discharge structure is coupled with the development of overpressure in the middle and the Miocene, the hydrocarbon generation of the source rocks and the active phase of the structure. Distribution, indicating that the late Miocene superpressure fluid was migrated to the upper slope of the western margin in a large scale, while the upper part of the upper part of the Pliocene converged to the high point of the central uplift. As an external triggering mechanism, the strike slip extrusion is essential for the formation of vertical discharge structures in the East. On the one hand, the vertical difference of the compressive strength can lead to two intensities in the deep level. On the other hand, the sand body of the shallow layer is weak two times; on the other hand, the sand body caused by the tectonic extrusion is more than 500 m, and the uplift accelerates the convergence of the deep deep overpressure fluid to the shallow height, and the local pressure stress coupling is formed. The joint action of the two is sufficient to disturbance the pressure stress coupling effect of the shallow weak overpressure in the region, and the hydraulic fracture.3 is formed in the East. The storage capacity of overpressure oil and gas in C1, C2 gas field is different, and the opening degree of the system is different, and the gas composition, carbon isotope differentiation, the upper middle Neocene sandstone formation process and the mineral composition difference. (1) the storage capacity of overpressure oil and gas in C1 gas field is less than 6 MPa, even up to 0, while the storage capacity of super pressure oil and gas in C2 gas field is generally higher than that of about 6MPa to 7MPao C1, C2 gas field The preservation ability of overpressure oil and gas is different, indicating the difference of opening degree of the system. (2) C1, C2 gas field has the same hydrocarbon source rocks, but the composition and isotopic analysis show that the 11 parameters of all hydrocarbon gas samples in C2 gas field increase uniformly with maturity, and the Delta n-iC4 of all hydrocarbon gas samples in C1 gas field is marked by the negative bias of increase relative to maturity. The other 10 parameters increase the negative deviation of the hydrocarbon gas of.C1 gas field with the uniform forward migration with the maturity. It is contrary to the increase of nC4/iC4, the weight of 813nC4 and 813iC4 and the increase of delta 13nC4/513iC4 in the process of increasing the maturity of the butane isomers in the closed pyrolysis experiment, indicating the occurrence of hydrocarbon gas loss under the open degree of the high system. In the low maturity stage of the hydrocarbon source rock, the formation gas is difficult to be preserved, while the high mature hydrocarbon gas or the over ripe inorganic carbon dioxide is relatively enriched. In the low open degree (closed) system, the gas generated from the different mature stages of the source rock will be efficiently preserved, but the preferential enrichment of nitrogen gas in a large number of low maturity stages will dilute the high maturity to a large extent. Hydrocarbon gas or over ripe inorganic carbon dioxide. (3) C1, the middle Miocene sand body in C1, C2 gas field all originate from Yu Yue East material source area, experience the same transport and deposition process, but the thin slice statistics or X diffraction analysis shows that the content of the Miocene sandstone feldspar particles in the C1 gas field is low, kaolinite, imimon mixed layer is high, rich in ferric dolomite cementation, C2 gas field The content of the Miocene sandstone feldspar, the chlorite content is high, the kaolinite and the imimon mixed layer is low, which is rich in the middle Miocene sandstone feldspar particles in the calcite cementing.C1 gas field. The chlorite content is lower than the C2 gas field, indicating a relatively stronger dissolution. The dissolution of the chlorite releases a large amount of Mg2 + and Fe2+, which helps the rich Mg-Fe carbonate rocks in the C1 gas field. The Miocene sandstone in the cemented.C1 gas field is still enriched in the cemented.C1 gas field and is still enriched with K+ sensitive imimon. Kaolinite indicates that there is a loss of K+ in the process of dissolution and precipitation. The salinity of the middle Miocene sandstone in the C1 gas field is lower than that of C2 gas field, and also indicates C1 gas in the upper Miocene sandstone in the C1 gas field. The high open degree of brine discharge directly leads to the loss of material in the sandstone internal formation of the upper Miocene sandstone in C1 gas field, and the dissolution and precipitation material is unevenly. The porosity of the Miocene sandstone in the C1 gas field is improved by the high open degree of brine relief, but the porosity is only 1vo1% to 4 vo1% And the improvement period of physical property is not earlier than hydrocarbon filling period. Therefore, the pore improvement has limited contribution to hydrocarbon accumulation.

【學(xué)位授予單位】：中國地質(zhì)大學(xué)
【學(xué)位級(jí)別】：博士
【學(xué)位授予年份】：2016
【分類號(hào)】：P618.13

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相關(guān)期刊論文 前1條

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本文編號(hào)：1861095