Salym Petroleum Development (SPD) has embarked on an ambitious Oil Field Management Improvement Program with as key objectives to:• Optimise Production (2.5% additional production through reduction of Locked-in-Potential and better reservoir pressure maintenance; unscheduled deferment less than 1% through reduction of ESP trips).• Increase Ultimate Recovery (Increase RF by 1%; platform for future EOR project; robust basis for infill drilling).• Reduce OPEX (increase ESP mean time between failure; contain chemical consumption costs; in field staff journies reduced by 10% /annum; less than 3 non-critical loss of integrity incidents per year).
In Russia many operators are challenged with the goal to increase production on oil and gas fields by drilling new wells or by using enhanced completion designs in the old ones. The latter is significantly less expensive, hence is preferable. The transition from completion to production on new and workover wells requires optimal clean up and the removal of the perforation damage to achieve maximum productivity.Perforating in the low formation pressure West Salym field has historically been performed overbalanced using wireline or with static underbalance using tubing conveyed perforating (TCP) with immediate well kill to remove guns. These perforating techniques, do not provide sufficient cleanup of the perforation tunnels and leave out significant perforation skin. A novel tubing conveyed perforating (TCP) technique using the dynamic underbalance effect combined with an afterperforation inflow testing was applied in the West Salym field. The goal was to achieve maximum productivity and to record the pressure transient. Deep penetrating charges were also used to bypass near wellbore damage and maximize potential results.A customized TCP test string was designed for 7 in. (178mm) casing that had two sets of gauges installed at different depths, and a production valve for the in-flow surge. The test string allowed to conduct a perforation inflow test to estimate post perforation skin, productive zone permeability and reservoir pressure.The operations were performed on 10 wells (5 workover wells and 5 new wells). Inflow pressure data on 5 wells, which allowed us to make conclusive estimates of skin, showed negative values. Improved productivity exceeded expected values by 10% on average.Dynamic underbalanced perforating has enabled us to obtain clean perforation tunnels and resulted in an average 50% production increase in comparison to the average field production.
Shell China Exploration and Production Company and its affiliates are operating in the pioneering Joint Cooperation Project (JCP) in the Sichuan Basin that targets unlocking the Lower Silurian Longmaxi shale gas play. Since 2010, both verticals and horizontals have been drilled and completed with various hydraulic fracturing technologies implemented. Supported by extensive data gathering and analysis, the hydraulic fracturing stimulation practices have significantly evolved to improve the quality and repeatability of completion results. This paper reviews the development of hydraulic fracturing stimulation practices in Longmaxi shale gas play in the studied area.Unlike most of the North American shale gas plays, the Longmaxi shale gas play is characterized by high formation pressures, close-to-overburden in-situ minimum stresses, low horizontal stress anisotropy, and regionally active tectonics, the combination of which presents unique challenges to hydraulic fracturing stimulation. The combination of these geologic, geomechanical and petrophysical characteristics result in high treating pressure, difficulty in proppant placement, constrained fracture height and complex fracture geometry. However, successful fracturing executions have been achieved by applying technologies including, but not limited to, limited entry perforation design and hybrid fluid systems, advanced monitoring including microseismic and Diagnostic Fracture Injection Test (DFIT) technique, etc. The completion parameters such as lateral length, stage spacing, number of clusters per stage, perforation shots per cluster, fluid type, fluid/proppant volume, treating rate, proppant selection have all been optimized as part of the learning curve.Key fracture design parameters such as the preferred treating rate, customized fluid design and pumping schedule for the play are discussed. This paper also demonstrates the learning of the fit-forpurpose hydraulic fracturing stimulation design from the perspective of successful and repeatable delivery of the fracture treatment.
After dozens of exploration and appraisal wells were drilled, fractured and tested in the Lower Silurian Long Ma Xi (hereafter referred to as LMX) shale formation in Sichuan basin since 2009, several blocks have now entered into the development phase. Hydraulic fracturing stimulation is vital to the performance of shale gas wells as well as the economics since it represents about half of the total well cost. Aiming at increasing production, most operators focus on enlarging Stimulated Rock Volume (SRV), a common means for which is to increase the injected fluid volume. Whilst injecting more fluid will lead to an enhanced SRV during the fracture stimulation process, how much of it is effective SRV under closure stress is often unknown and tends to be field specific. It is possible that a large portion of the injected fluid and consumed energy is actually ineffective in terms of adding more production rate. Based on some early production data of wells in Fushun-Yongchuan (herein after refer to as Fushun) block and its sensitivity analysis to completion parameters, it is found that the amount of injected fluid volume does not obviously impact the performance. Instead, proppant intensity; the volume of 100 mesh natural sand carried by slick water; and proppant pack continuity are all more important variables. These variables are not generally the focus of most operators in the area. A concept for improving the effective or propped SRV is developed as a result, with key points summarized as below: Significantly reduced frac fluid volume compared to original base design; Enhanced proppant intensity; Significantly increased 100 mesh sand volume; Continuously adding proppant to achieve best proppant pack continuity at fracture face; Tailored frac fluid design to meet the proppant transportation needs meanwhile minimize the residue damage The above concept has been put into field trials in Fushun area. Field execution went well and demonstrated higher efficiency in terms of operation time, however did require a higher level of onsite QAQC and real-time engineering control. Early production data has been gathered and analyzed to assess the performance impact of this approach, indicating that a consistent performance improvement has been observed. This new shale gas frac concept is practical and beneficial on both operational efficiency and well stimulation performance.
Summary Reservoir monitoring in the course of current field development is the key factor for continuous short-term production optimization and achievement of best economics throughout the lifecycle of the field. Therefore, Salym Petroleum Development (SPD) carries out a set of actions focused on controlling current development parameters. The report describes the processes of planning, geological and downhole logging data acquisition and methods of interpretation thereof during the active development phase of the Salym group of fields. Key emphasis is assigned to analysing the efficiency of different methods for solving the key tasks of development control.
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