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Gas-condensate production studies are run to determine the paramount data for gas and condensate reserve evaluations, field characterizations and facilities installations. Currently, there is enough number of workflows, rules, and recommendations to conduct gas-condensate metering tests (GCMT) with data processing and results presenting, however, all such documents imply the use of traditional measurement instruments, which are the conventional separators. Over the last decade, multiphase flowmeters have become widely known and they provide non-separating measurements of all produced phases a single measuring point. The paper presents a unique GCMT workflow using a Vx multiphase metering technology, which considers the use of individual fluid properties models (or PVT models), designed for accurate flow rate measurements in gas condensate wells, when permanent measurements are arranged for individual or a group of gas condensate wells. The workflow implementation has allowed creating a comprehensive alternative to traditional separation technologies for conducting GCMTs in gas condensate wells of Achimov deposits in Western Siberia.
Gas-condensate production studies are run to determine the paramount data for gas and condensate reserve evaluations, field characterizations and facilities installations. Currently, there is enough number of workflows, rules, and recommendations to conduct gas-condensate metering tests (GCMT) with data processing and results presenting, however, all such documents imply the use of traditional measurement instruments, which are the conventional separators. Over the last decade, multiphase flowmeters have become widely known and they provide non-separating measurements of all produced phases a single measuring point. The paper presents a unique GCMT workflow using a Vx multiphase metering technology, which considers the use of individual fluid properties models (or PVT models), designed for accurate flow rate measurements in gas condensate wells, when permanent measurements are arranged for individual or a group of gas condensate wells. The workflow implementation has allowed creating a comprehensive alternative to traditional separation technologies for conducting GCMTs in gas condensate wells of Achimov deposits in Western Siberia.
Well completion practices in high-temperature, high-pressure carbonates are challenging especially for long lateral horizontal wells intended for fracturing applications. An integrated approach involving intervention and fracturing design and reliable post-fracturing flow measurements is very critical to optimize the well performance. After initial intervention complexities due to wellbore accessibility in a 6,250-ft cemented lateral initially planned with 13 fracturing stages resulting in the loss of many operational days, a revamped engineering workflow was planned for Well-A. As a first step, Coiled Tubing (CT) was used for abrasive jetting perforations, cleanout, and acid squeeze functionalities with a novel bottomhole assembly (BHA). The BHA was equipped with a real-time telemetry to optimize intervention to a single run. Having real-time bottomhole parameters helped in perforating the desired zones accurately and enhanced the injectivity by creating cleaner perforation tunnels. Stages were reduced to five with an optimized perforation design based on rock typing approach, and short clusters were designed to divert the fracture fluids effectively using multimodal particulate diversion. Each fracturing stage was isolated with a mechanical plug. A novel high-frequency pressure monitoring technique that analyzes fluid entry points from water hammers was utilized during the fracturing treatments to analyze on-the-fly diversion efficiency and optimize further treatments. A multiphase flowmeter was utilized to enhance milling and flowback to minimize losses and manage the choke schedule based on actual well performance leading to better fracture cleanup and recovery. The production performance of Well-A was compared with two offset horizontal wells drilled azimuthally parallel, intersecting the same carbonate sublayer. The post-fracturing absolute production enhancement analysis showed 11 to 15% improvement, and productivity index (PI) improvement was 40 to 63% when normalized by stage count. The effective integration of multiple technologies was applied successfully on the candidate well, yielding enhanced operational efficiency with optimized production performance.
The development of tight carbonate reservoirs is moving towards drilling and completing wells with longer laterals. This leads to challenges of longer completion time, high number of fracturing stages, longer interventions, and eventually higher costs. Design cycle implementation is required to devise an engineered strategy to mitigate these challenges. Lateral landing was conducted based on the cross-section grid consisting of two offset horizontal wells completed with up to 13 fracturing stages. A longer lateral greater than 6,000 ft was drilled compared to 4,000 ft in offset wells to get the production potential. With a strategic design involving engineered chemistry and numerical simulation models, a cluster design was devised to reduce to stages. A mathematical algorithm employing tube wave velocity calculations was used as a diagnostic to ensure diversion success after each stage. The horizontal lateral was landed traversing the prolific layer. Stage reduction sensitivity simulations were conducted using multiphysics numerical models and novel beta factor workflows to evaluate the extent of stage reduction. The design was extended to plan for five stages only, with increased number of perforation clusters per stage. The reliable diversion chemistry utilized was accompanied by a revised perforation length as dictated by the beta factor workflow. A total of 39 clusters, 2-ft each, were distributed across 6,000 ft with four mechanical isolation plugs. A novel nonintrusive diagnostic model built on mathematical fundamentals of wave travel time was used with a Bayesian statistical approach after each diversion pill placement to ensure fracture fluid entry points and enough coverage in each stage. The high fluid viscosity and operating pumps during the water hammer events resulted in low signal-to-noise ratio in the input data. To overcome these limitations, the water hammer events were processed with a combination of two newly developed algorithms: predictive deconvolution and comb filter, which produced more robust results than the traditional approach. Consequently, the well production was analyzed to show equivalent or higher productivity index compared to the offset laterals with up to two times higher stage count. The paper presents a unique example in which an experiment was fully engineered from design to evaluation and monitored with reliable diagnostics. This example gives a blueprint for future completion designs.
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