A new method for assessing tight oil, with application to the Lucaogou Formation in the Jimusaer depression, Junggar Basin, China

AAPG Bulletin ◽  
2020 ◽  
Vol 104 (6) ◽  
pp. 1199-1229 ◽  
Author(s):  
Junqing Chen ◽  
Xiongqi Pang ◽  
Xulong Wang ◽  
Yingxun Wang
Keyword(s):  
Junggar Basin ◽  
New Method ◽  
Tight Oil ◽  
Lucaogou Formation

The tight oil potential of the Lucaogou Formation from the southern Junggar Basin, China

Fuel ◽  
2018 ◽  
Vol 234 ◽  
pp. 858-871 ◽  
Author(s):  
Qingyong Luo ◽  
Lei Gong ◽  
Yansheng Qu ◽  
Kuihua Zhang ◽  
Guanlong Zhang ◽  
...  
Keyword(s):  
Junggar Basin ◽  
Tight Oil ◽  
Lucaogou Formation

scholarly journals Characterization and Consecutive Prediction of Pore Structures in Tight Oil Reservoirs

Energies ◽  
2018 ◽  
Vol 11 (10) ◽  
pp. 2705 ◽  
Author(s):  
Zhaohui Xu ◽  
Peiqiang Zhao ◽  
Zhenlin Wang ◽  
Mehdi Ostadhassan ◽  
Zhonghua Pan
Keyword(s):  
Pore Structure ◽  
Capillary Pressure ◽  
New Method ◽  
Tight Oil ◽  
Type I ◽  
Sweet Spot ◽  
Sem Images ◽  
Pore Structures ◽  
Lucaogou Formation ◽  
Two Samples

The Lucaogou Formation in Jimuaser Sag of Junggar Basin, China is a typical tight oil reservoir with upper and lower sweet spots. However, the pore structure of this formation has not been studied thoroughly due to limited core analysis data. In this paper, the pore structures of the Lucaogou Formation were characterized, and a new method applicable to oil-wet rocks was verified and used to consecutively predict pore structures by nuclear magnetic resonance (NMR) logs. To do so, a set of experiments including X-ray diffraction (XRD), mercury intrusion capillary pressure (MICP), scanning electron microscopy (SEM) and NMR measurements were conducted. First, SEM images showed that pore types are mainly intragranular dissolution, intergranular dissolution, micro fractures and clay pores. Then, capillary pressure curves were divided into three types (I, II and III). The pores associated with type I and III are mainly dissolution and clay pores, respectively. Next, the new method was verified by “as received” and water-saturated condition T2 distributions of two samples. Finally, consecutive prediction in fourteen wells demonstrated that the pores of this formation are dominated by nano-scale pores and the pore structure of the lower sweet spot reservoir is more complicated than that in upper sweet spot reservoir.

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