Baikouquan Formation have been found in the last few years in Mahu Sag, Junggar Basin. Many studies have been conducted to describe the sedimentological complexity of reservoirs. However, few of them have been focused on the depositional characteristics and associated controlling factors in Baikouquan Formation. In this study, analysis of cores, thin sections, wireline logs, and seismic volume were carried out obtain detailed descriptions and interpretations of sedimentary microfacies, depositional evolution, and associated controlling factors. The results indicate that seven sedimentary microfacies are identified in Baikouquan Formation. Furthermore, depositional evolution of fan delta systems from bottom to top of Baikouquan Formation shows retrogradation in general. Tectonic activities along the northwestern fault zone, rising lake levels, arid climate, and high temperature together exert the controls on depositional evolution of fan delta systems in Baikouquan Formation.

The Ke‐Bai Fault Belt in northwestern Junggar Basin has gained robust insights and wide attention on large‐scale hydrocarbon discoveries in the Carboniferous volcanic rocks. The integrated analysis of wireline logs, image logs, core photographs, thin sections, and scanning electron microscope allows the description and interpretation of volcanic facies and volcanic reservoirs, as well as their responses to controlling factors. The results indicate that three types of lithology are identified based on cores, including volcanic rocks, followed by sedimentary rocks and metamorphic rocks. In addition, explosive facies, effusive facies, volcanic sedimentary facies, and sub‐volcanic facies are delineated according to spatial distribution, occurrence condition, and appearance characteristics of volcanic products. Furthermore, the characteristics of reservoir space (including pores and fractures) are analysed and described. Finally, the controls on the characteristics of volcanic reservoirs are revealed, including volcanic lithofacies, tectonic movements, and diagenesis.

MH oilfield, located in the Junggar Basin, in Xin Jiang Province of northwest China, is the world largest conglomerate reservoir with a fan-delta sedimentary environment. This long-term project can be traced back to 2012, and since then has gone through many technology revolutions and optimizations. At the end of 2017, the drilling performance of one main block inside MH oilfield, M18, was not optimistic when compared with other blocks. The extremely high formation hetergenity of the field made it very challenging to choose the right bit at the right time. This long-term project has brought to light the dedicated, quantifying study of the rock property differences throughout this field and inside each block. To solve this tough bit selection problem, geologic data was interpreted for engineering use. Two lines of data were processed. One was offset analysis based on the current run records to optimize bit designs, and the other was rock property interpretation and simulation to predict the formation variation, which covers the unconfined compressive strength (UCS), confined compressive strength (CCS) abrasion, impact simulations, layer correlations, statistical analysis and contour mappings of interest zones. This paper will summarize the field history, delineate the bit design lineage in this long-term project, and then mainly focus on geology simulations. The objective of this paper is bring to light the importance of CCS simulations to predict the bit performance and help the bit design and selection; provide a bit design lineage and bit optimization workflow for the drilling operation to optimize the inventory utilization and streamline the decision-making loop; provide a case study with coordinating multiple disciplinary teams to achieve specified objective; and provide a concept of integration of geology and engineering in the

No abstract

No abstract