During most hydraulic fracturing operations, coiled tubing (CT) is used as a contingency option for well cleanup in the case of sand screenout. An alternative improvised solution is presented introducing a single-shot circulating valve into the frac string to help minimize additional resources related to CT procedures, thus reducing costs and enhancing operational performance. The tool is positioned above the retrievable frac packer to provide circulation capability to reverse out proppant sand without well intervention activities. Setup, operating procedures, concept evaluation, and performance of the single-shot circulating valve used to reverse proppant sand from the frac string are discussed. A single-shot circulating valve in the frac string provides additional liquid flow pass for recovering excess sand inside the frac string to the surface. Intensive laboratory testing was performed to evaluate tool function in worst-case scenarios of a highly deviated well with proppant sand packed above the circulating ports. During field operations, activated pressure tolerance was defined by incorporating rupture-disk reliability and temperature decrement effects during hydraulic fracturing to help ensure the operating pressure did not impair the fracturing operation or well integrity. Lastly, a cleanout procedure was meticulously planned to help prevent pipe sticking situations caused by sand fallout in the annulus. The single-shot circulating valve, typically deployed during drillstem testing (DST) operations, proved successful circulating out the proppant-sand column packed inside the tool during both laboratory testing and field operations. With precise hydrostatic pressure calculations, the burst pressure was reliable, meaning no premature activation occurred, and the rupture-disk burst within the designed surface pressure tolerance of ±400 psi. During reverse circulation, pumping pressure was maintained within an acceptable range (the maximum pumping rate across the circulating ports was 8 bbl/min) and no visual tool damage occurred. Deploying comprehensive engineering and operating procedures (e.g., defining the operating envelope to maintain a higher casing pressure than drillpipe pressure), the frac string and retrievable downhole frac packer were free of sand and successfully retrieved, even during a screenout scenario. Based on the success of the prolonged two-year fracturing operations, the proposed approach is appropriate for fracturing using a single-shot circulating valve as the primary contingency equipment during screenout, replacing CT intervention for this application. This alternative method resulted in improved safety and operational efficiency by eliminating on-rig CT operations when screenout pressure is trapped in the string in addition to significant cost savings attributed to eliminating the extra standby resources of a CT package. This innovative approach, which applies functions of a downhole well-testing tool during hydraulic fracturing, requires both circumspect engineering consideration to define a proper operating envelope and comprehensive operational procedures to help mitigate operational risks.

This paper aims to elaborate the strategy for operational and cost efficiency improvement by providing an example of a successful case of rig selection strategy for Hydraulic Fracturing Operation in S1 oil field Thailand. The integrated workflow proposed involves all concerned parties to specify the scope of work, analyze internal and external strengths and weaknesses, evaluate possible scenarios, and identify the procurement strategy. As a case of rig selection for fracturing operation in the heterogeneous sandstone, committing the number of candidates before drilling is impossible. Therefore, the typical criteria for fracturing rig selection consider rig move mobility and flexibility in candidate selection. However, in a proven area, the uncertainty of candidate confirmation is manageable. Reservoir engineers provide the number of candidates in 3 scenarios for sensitivity analysis. SWOT analysis and the market survey reveal the possibility to improve both performance and cost by using a warm-stack skidding rig instead of a truck-mounted rig. The sensitivity analysis by using the historical data of each type, indicates that the number of candidates and rig cost play a significant role in cost saving. As a result of analysis and strategy, the operation performance improvesby 34% (2 months reduction) leading to cost-saving by 1MM USD or 24% of the time-dependent cost.