Lithologic Reservoirs ›› 2026, Vol. 38 ›› Issue (4): 191-200.doi: 10.12108/yxyqc.20260417

• PETROLEUM ENGINEERING AND OIL & GAS FIELD DEVELOPMENT • Previous Articles    

Fine geological modeling method for Jurassic Sangonghe Formation condensate gas reservoir in Mobei uplift of Junggar Basin

DING Yajie(), LI Xiang, HAN Zijian, XIE Lei, WEI Pu, WEI Ting(), LUO Yang, MA Xinzhao   

  1. Shixi Oilfield Operation District， PetroChina Xinjiang Oilfield Company， Karamay 834000， Xinjiang， China
  • Received:2025-10-30 Revised:2025-12-09 Online:2026-07-01 Published:2026-07-06
  • Contact: WEI Ting E-mail:sxytdyj@petrochina.com.cn;sxytwt1@petrochina.com.cn

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Abstract:

In the middle to late stage of low-permeability condensate gas reservoirs development， rapid deliverability decline and reduced recovery due to condensate oil blockage often occur. Taking No. 1 sandbody in the second member of Jurassic Sangonghe Formation in Qianshao 4 well block in Mobei uplift of Junggar Basin as an example， a high-precision numerical simulation model was established by combining multi-scale parameters integration with wellstream phase-behavior correction， and remaining gas distribution prediction and potential-tapping schemes evaluation were conducted. The results show that：（1） The thickness of No. 1 sandbody in the second member of Jurassic Sangonghe Formation in Qianshao 4 well block in Mobei uplift of Junggar Basin is about 20 m，the average porosity is about 12%， the average permeability is about 1.5 mD， with strong heterogeneity and poor local connectivity. （2） Using data collaboration to constrain sandbodies distribution and porosity/permeability parameters， combining fluid composition inversion in condensate gas wells and bottomhole pressure coupling， an integrated model of “geology-phase behavior-wellbore” was established，significantly improving the characterization accuracy of sandbody architecture and porosity/permeability parameters. The correlation coefficients between the modeling porosity/permeability and measured values were greater than 0.99. The fitting accuracy between the calculation results of the model and historical condensate gas production is greater than 96%， revealing that the high part of well Qianshao 401 in the study area represents a typical remaining gas enrichment zone of “high gas saturation but poor connectivity”. （3） Based on remaining gas distribution， the proposed lateral drilling potential-tapping scheme for well Qianshao 401，can provide an additional recoverable reserve of 0.37×108 m3 and increase daily gas production by 4×104 m3. The prediction results suggest that the well can achieve stable production until 2030 if the constant gas recovery rate of 5.1% is maintained.

Key words: condensate gas reservoir, low-permeability reservoir, numerical simulation, geological modeling, remaining gas distribution, enhanced oil recovery, Sangonghe Formation, Jurassic, Mobei uplift, Junggar Basin

CLC Number: 

  • TE319

Fig. 1

Top structure of Qianshao 4 well block in Mobei uplift（a） and comprehensive stratigraphic column of Jurassic （b）， Junggar Basin"

Fig. 2

Well-tie correlation of Jurassic Sangonghe Formation in well Qianshao 401-well Qianshao 4-well Qianshao 402_H of Mobei uplift， Junggar Basin"

Fig. 3

Distribution features of porosity （a） and permeability （b） of No. 1 sandbody of the second member of Jurassic Sangonghe Formation in Qianshao 4 well block， Mobei uplift， Junggar Basin"

Fig. 4

Thickness contour lines of No. 1 sandbody of the second member of Jurassic Sangonghe Formation in Qianshao 4 well block， Mobei uplift， Junggar Basin"

Fig. 5

Method workflow of geology-phase behavior-wellbore integration for No. 1 sandbody of the second member of Jurassic Sangonghe Formation in Qianshao 4 well block， Mobei uplift， Junggar Basin"

Fig. 6

Schematic diagram of the bottomhole pressure calculation process of multiphase-flow flash evaporation for No. 1 sandbody of the second member of Jurassic Sangonghe Formation in Qianshao 4 well block，Mobei uplift， Junggar Basin"

Fig. 7

Comparison of geological modeling porosity，permeability with measured values of No. 1 sandbody of the second member of Jurassic Sangonghe Formation in Qianshao 4 well block， Mobei uplift， Junggar Basin"

Fig. 8

Geological modeling profiles of No. 1 sandbody of the second member of Jurassic Sangonghe Formation reservoir in Qianshao 4 well block， Mobei uplift， Junggar Basin"

Table 1

Wellstream components of oil and gas reservoir in No. 1 sandbody of the second member of Jurassic Sangonghe Formation in Qianshao 4 well block， Mobei uplift， Junggar Basin"

组分 N2 CO2 C1 C2 C3 C4 C5 C6 C7 C8 C9 C10 C11+
ϕ（组分）/% 1.823 0.086 59.31 3.28 0.512 0.560 0.471 0.373 0.864 3.234 1.029 1.371 27.10

Fig. 9

Experimental fitting results of condensate liquid volume of No. 1 sandbody of the second member of Jurassic Sangonghe Formation reservoir in Qianshao 4 well block， Mobei uplift， Junggar Basin"

Fig. 10

Bottomhole pressure calculation results with different testing methods for No. 1 sandbody of the second member of Jurassic Sangonghe Formation reservoir in Qianshao 4 well block， Mobei uplift， Junggar Basin"

Fig. 11

Historical fitting results of geological model on bottomhole pressure and oil-gas production of No. 1 sandbody of the second member of Jurassic Sangonghe Formation reservoir in Qianshao 4 well block， Mobei uplift， Junggar Basin"

Fig. 12

Current gas saturation numerical simulation of No. 1 sandbody of the second member of Jurassic San-gonghe Formation reservoir in Qianshao 4 well block， Mobei uplift， Junggar Basin"

Fig. 13

Predicted gas production curves of No. 1 sandbody of the second member of Jurassic Sangonghe Formation reservoir in Qianshao 4 well block，Mobei uplift， Junggar Basin"

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