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1 DOI /j.issn P E T R O L E U M G E O L O G Y ; ; TE A t [1]

2 [2] 4 [3] [4] [2] [2] [5] 3 [6] 95.3%

3 P E T R O L E U M G E O L O G Y [7] CFD 1 TOC 3 S 1 +S 2 20mg/g I H 500mg/g mg/g HC HC/TOC 10% [911] [8] CFD Fig.1 Geochemical composite profile of source rocks of Well CFD in Bohai Area g vg 2% 5% S 1 +S 2 10mg/g 30mg/g 1% 2% 4% S 1 +S 2 6mg/g mg/g 20mg/g WC 2

2.1.1 CFD 1 TOC 3 S 1 +S 2 20mg/g I H 500mg/g 800 900mg/g HC 3000 10-6 HC/TOC

4 2 WC Fig.2 Geochemical characteristics of organic facies of source rocks of Shenhu-Wenchang Formation in Well WC of Wenchang sag 4- C 30 PY 1%5% %40% S 1 +S mg/g [12] LW [1317] 13

5 P E T R O L E U M G E O L O G Y ; 13- [1822] 1 3 [23] HS PY Fig.3 Geochemical profile of source rocks of Well PY in Baiyun sag, east of Pearl River Mouth Basin g vg S HS dm ;

6 4 Fig.4 Diversity curves of pollen and algal fossils of Paleogene, west of Pearl River Mouth Basin a b c d I h g F m ; R.V. Tyson [24] APE A P E [25] 84 A P E A P E Tyson A P E P E E 3.3 ;

7 P E T R O L E U M G E O L O G Y 4 ; ; [26] 1 1 [1]. 3 [J]. 2008,30(6): [2]. [M]. 1997: [3]. [J]. 2001,22(2):3843. [4]. [J]. 2002,16(2): [5]. [M] : [6]. 4 [7]. 1 [M]. 1997: [8]. [J]. 1998,12(4): [9]. [M]. 1991: [J] (4):1423.

1 [5]. [M]. 1 1999:10541087. [6]. 4 [7]. 1 [M]. 1997:287297. [8]. [J].

8 E X P L O R A T I O N T E C H N I Q U E S [J]. 2003,49(2): [15] [8]. 29( 2): [J]. 2007,34(1):1318. [9]. [J]. 1987,22(2):163168, [J]. D 2007, 37( ):3642. [10]. [J]. 2008,43(4): [J]. 2003,49 (1): [11]. [J]. 1998,25(4):79. [J]. 2004,6(1): [12]. [J]. 2005,32(5):5961. [M]. : [13]. [J]. 2008,23 [J]. 1997,32( 1):16. [14]. [J]. [21]. [J]. 1995,16(1):1015. [J]. 1994, [16] 216. [17]. [18]. [19]. [20]. (4): ,11(6): [10]. [M]. [J]. 2000,20(1): : [11] Baskin D K. Atomic H/C Ratio of Kerogen as an Estimate of Thermal Maturity and Organic Matter Conversion[J]. AAPG Bulletin1997,81(9): [12]. [J]. 2000,14(6): [J]. 1996,1(2):611. [13]. [J]. 2001,15(2): [J]. 2009,21(1):18. [14]. [J]. [J]. 2006, 2005,16(4): (3): [15] [J]. 2007,28(3):3238. [16]. and Kimmeridge Clay Formations, U K onshore and [J]. 2005,16(4): [17]. [25]. LW3-1-1 [J]. [J]. 1996,10(4): ,19(2): [19]. [J]. 2000,29(4): [20]. [21].13-1 [22]. [23]. [M]. [24] Tyson R V. Late Jurassic palynofacies trends, Piper northern North Sea. In: Battern D J, ed. Micropaleontology and Palynology. Br Micropaleontol. Soc.Ser1989. [26]. [18]. [M]. 2004:

[17]. [18]. [19]. [20]. (4):339342. 2006,11(6):3337. 16 [10]. [M]. [J]. 2000,20(1):2327. 2001:79130. [11] Baskin D K.

9 C H I N A P E T R O L E U M E X P L O R A T I O N ABSTRACT ABSTRACT Practice and Effectiveness of Carbonate Oil-Gas Reservoir Exploration-Development Integration in Tarim Oilfield/Zhou Xinyuan, Yang Haijun//PetroChina Tarim Oilfield Company, Korla City, Xinjiang Uygur Autonomous Region Abstract: Large oil and gas fields have been discovered in marine carbonate rock area in recent years; proved oil and gas equivalent surpassed 100 million tons for three consecutive years; crude oil production saw significant and steady growth. Scale returns have been obtained in ultra-deep, low-abundance, and highly anisotropic oil-gas reservoir exploration and development. This profits from the goal of maximum benefit, actively transforming development mode, taking Òfour enhancementsóas the focus, i.e. enhancing the success rate of drilling, enhancing the single well production, enhancing the recovery, and enhancing drilling rates, and vigorously implementing exploration-development integrationñthe integration of organizational structure, the integration of investment deployment, the integration of scientific research and production, the integration of production and organization, the integration of engineering and geology, and the integration of surface and underground. Production and reserves of carbonate rock were increased; good and scale profits were obtained. Key words: exploration-development integration; carbonate rock; increasing production and reserves; maximum benefit; Tarim Oilfield Growth and Paleoecological Marker of High-Grade Source Rocks in China Marginal Seas/Huang Zhengji//Beijing Branch of CNOOC Energy Technology & Services Limited, Beijing Abstract: Many Cenozoic sedimentary basins developed in China marginal seas, of which the chief oil source rocks are lacustrine ones developed in rifting phase (developmental phase). Representative source rocks are the third member of Eocene Shahejie Formation in Bohai Sea, the Eocene Liushagang Formation in Beibuwan Basin, the Eocene Wenchang Formation in Pearl River Mouth Basin, and the Eocene Yueguifeng Formation in the western depression of East China Sea Basin. Chief gas source rocks of many basins are source rocks in coal measure, which developed in rifting phase (decline phase). The representative source rocks are the Oligocene Yacheng Formation in Qiongdongnan Basin, the Eocene-Oligocene Enping formation in Pearl River Mouth Basin, and the Eocene Pinghu Formation in eastern depressions of East China Sea Shelf Basin. The formation of high grade source rocks depends on abundant organic matter and paleoenvironment suitable for preservation and transformation of organic deposition. Research on the variations of palynoflora, algae and fragmentary organic matter that have been conserved in strata is an effective channel for investigating the paleoenvironment and distinguishing the growth of high grade source rocks. So, characteristics of paleoecospecies and fragmentary organic matter are feasible paleoecological marker for forecasting the growth of high grade source rocks. To study vertical and horizontal organic facies in suitable strata in combination with the paleoenvironment, paleobiology, and organic geochemistry when organic matter formed is reasonable methology for forecasting the distribution of high grade source rocks. Key words: lacustrine source rocks; coal-measure source rocks; organic matter; paleoenvironment; paleoecospecies; organic facies; rifting phase of basin; China marginal seas Analysis and Evaluation of Beneficial Gas Exploration Zone Based on Remote Sensing Geophysical and Geochemical Methods in Sanhu Area of Qaidam Basin/Qi Xiaoping 1, Zhang Youyan 1, Yang Hui 1, Yu Shiyong 1, Liu Zhan 2, Sun Changqing 3, Liu Zhiqiang 4 // 1. PetroChina Research Institute of Petroleum Exploration & Development, Beijing ; 2. China University of Petroleum (East China), Qingdao City, Shandong Province ; 3. Wuxi Research Institute of Petroleum Geology, Sinopec, Wuxi City, Jiangsu Province ; 4. Research Institute of Exploration and Development, PetroChina Qinghai Oilfield Company, Dunhuang City, Gansu Province Abstract: Quaternary biogenic gas reservoir located in Sanhu area in Qaidam Basin features in low altitude structures, low compaction effect, high porosity, shallow burial depth and big thickness. For these reasons, gas reservoir has particular surface topography, geophysical and geochemical exploration abnormalities. On this basis, this paper explained and predicted shallow gas with remote sensing, geophysical and geochemical exploration methods. Through contrastive analysis of such gas fields as Tainan and Sebei No.1, this paper put forward the distributive characteristics that Sanhu gas reservoir agreed with negative gravity anomaly to a high degree, and the anomaly of high methane values of low-amplitude structure and chemical exploration, and predicted three zones favorable for exploration such as the W-

proved oil and gas equivalent surpassed 100 million tons for three consecutive years; crude oil production saw significant and steady growth.

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