Production Controlling Factors of the Longmaxi Shale Gas Formation - A Case Study of Huangjingba Shale Gas Field


 The shale gas in Jingmen area in China has unique features different from North America shale plays, such as abundant natural fracture corridors with complex patterns and distributions, formed through multiple tectonics in geological history, high in-situ stresses with extreme variations of heterogeneities and anisotropies, and highly laminated rocks. Wells drilled in this area are often less stable than comparable wells drilled into non-laminated rocks. Hydraulic fracturing has encountered many difficulties, such as high treating pressure, difficulty in proppant placement, constrained fracture height and complex fracture geometry. It has been recognized that optimizing lateral landing and wellbore trajectory is essential to reduce operation risks and improve productivities.
 An integrated 3D shared earth model was constructed with 0.5-m vertical resolution of the targeted sweet section to capture vertical heterogeneities measured from logs through integrating seismic, geological structure, log, and core data. This model includes anisotropic mechanical properties, in-situ stress field, and multiscale natural fracture systems. Near borehole induced stress was computed accounting formation anisotropies, and wellbore shear failure mechanism was modeled by a modified Plane of Weakness (PoW) model. The model can predict the extent of failure region around the wellbore and then provide mud weight window for safe and effective drilling. The fracturing simulations were performed with Unconventional Fracture Model (UFM) that models the hydraulic fracturing process in complex formations with pre-existing natural fractures including interaction with natural fractures and between hydraulic fracture branches (i.e., stress shadow effects). Numerical reservoir simulations were computed to forecast productivities of different lateral landing and well trajectory designs and provide optimal strategy.
 A comprehensive integrated workflow was generated from drilling to production through stimulation to optimize well planning. This study proposed the best interval L111 for lateral placement and optimal well trajectory along NE23° for wellbore stability and hydraulic fracturing effectiveness to reduce operation risks and ahicheve highest productivities considering unevenly well-developed natural fractures, significant heterogenetic and anisotropic in-situ stress, Guanyinqiao limestone formation and highly laminated rock.
 This integrated workflow represents the comprehensive multidisciplinary approach to coupling geophysics, geology, petrophysics, geomechanics, wellbore stability, complex hydraulic fracture propagation, and production simulation models aimed towards optimizing lateral landing and well trajectory. The implementation of this workflow guides drilling, stimulation and development of shale gas reservoirs in the most optimized and scientific way.

Application of Anisotropic Wellbore Stability Model and Unconventional Fracture Model for Lateral Landing and Wellbore Trajectory Optimization: A Case Study of Shale Gas in Jingmen Area, China

During horizontal well multi-stage fracturing (HWMF), superfractures are often identified. To promote the uniform propagation of multiple fractures, it is necessary to finely optimize the perforation cluster locations based on the geological and engineering parameters. This work proposes an efficient method to design the perforation cluster locations in consideration of the geoengineering sweet spots with similar mechanical properties. Well log data and the precise fiber optics (FO) monitoring results are combined to find the main influencing factors. The principal component is conducted by introducing correlation analysis and Random Forest. Moreover, the K-means++ clustering method is used to evaluate reservoir quality. The fracturing sweet index (FSI) is proposed to measure the fracturing performance of each category quantitatively. The proposed workflow is effectively validated by two production scenarios. Moreover, the workflow can automatically evaluate reservoir quality based on intelligent clustering methods. Compared with the original design, the updated design lowers the gap among multiple fractures within one stage and increases the well production by 20%–50%. This work is beneficial for the on-site treatment of its feasibility and generalizability.

The intelligent optimization of perforation cluster locations incorporating the fiber optics monitoring results


 Changning National Shale Gas Demonstration Area was established in 2012. Field Development of its Ning201 shale gas fields was geared up in 2014. By 2015, Changning area accomplished the construction of 15×108 m3/a production capacity. During early appraisal phase before 2014, average testing results of wells were 10~15×104 m3/d. In the end of 2016 and early 2017, average testing results of large numbers of wells across multiple pads achieved over 25×104 m3/d. Overall testing results of some pads have exceeded 180×104 m3/d per pad, and some of them may exceed 180×104 m3/d per pad in soon future. Through implementing geo-engineering integration, efficiency and effectiveness of field development have been steadily enhanced. This paper reviews our practices to establish and rapidly evolve the learning curve in this national demonstration area through geoengineering integration. Benefiting from geo-engineering integrated study, development options were systematically, proactively and effectively supported throughout the process of field development. Per the evolving understanding of reservoir and engineering challenges, adaptive technology and engineering solutions were exploited and optimized. A new geo-engineering model has been proposed which covers engineering applications of drilling, completion, production and development. Based on our gathered knowledge and experience, key contributing factors for marine shale gas development in Sichuan basin were thoroughly studied and summarized. They may include controlling factors of productivity, optimum production scheme, optimized well spacing, and so on. This paper also points out key areas for further improvement and enhancement in future.

Development Strategy Optimization of Ning201 Block Longmaxi Shale Gas

To address the issues of inefficient hydraulic fracturing on perforation clusters in shale gas horizontal wells caused by the inconsistent size of entrance holes on the casing, Stimstream shaped charge providing consistent hole and deep-penetration was introduced and its special performance was analyzed. Surface concrete target test and field test were conducted respectively to compare the performance between this kind of charge and conventional deep penetration charges made in China. In surface concrete target test, the average hole diameter of Stimstream shaped charge in 0°, 90°, 180°, 270° phasing is 9.4mm, 9.3mm, 9.3mm, 8.9mm, the average hole diameter of conventional deep penetration charges in 0°, 90°, 180°, 270° phasing is 9.3mm, 8.6mm, 6.5mm, 7.0mm respectively. The results shown that Stimstream shaped charge can provide uniform and big holes on the casing regardless of different clearance between perforating gun and casing. In three field testings, comparing the field data of S3406D Stimstream charge and domestic SDP35HMX25 shaped charges, it proven that S3406D can reduce the average hydraulic breakdown pressure by 2044.5 psi, 1189psi and 1261.5psi respectively, and reduce the average treatment pressure to pump proppant by 696psi, 652.5psi and 928psi respectively. It has remarkable effectiveness on reducing the breakdown pressure and treatment pressure of shale gas formations during hydraulic fracturing operation.

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Application of Stimstream Shaped Charge with Consistent Entrance Hole and Deep Penetration in Shale Gas Reservoir

An Integrated Approach to Ensure Horizontal Wells 100% in the Right Positions of the Sweet Section to Achieve Optimal Stimulation: A Shale Gas Field Study in the Sichuan Basin, China

Development of Multi-Scale and High-Resolution Integrated Earth Models in Silurian Longmaxi Shale Gas Field for Effective Full Field Development in Geographically Challenging Mountain Area, Sichuan Basin, South China

Three-Dimensional Full-Field and Pad Geomechanics Modeling Assists Effective Shale Gas Field Development, Sichuan Basin, China

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An Integrated Approach to Ensure Horizontal Wells 100% in the Right Positions of the Sweet Section to Achieve Optimal Stimulation: A Shale Gas Field Study in the Sichuan Basin, China

Production Controlling Factors of the Longmaxi Shale Gas Formation - A Case Study of Huangjingba Shale Gas Field

Development of Multi-Scale and High-Resolution Integrated Earth Models in Silurian Longmaxi Shale Gas Field for Effective Full Field Development in Geographically Challenging Mountain Area, Sichuan Basin, South China

Three-Dimensional Full-Field and Pad Geomechanics Modeling Assists Effective Shale Gas Field Development, Sichuan Basin, China