Horizontal wells are superior in production and recovery to conventional wells, however they are subjected to early water coning towards the heel (water can breakthrough anywhere in the well not only at the heel, due to permeability (K) variation and proximity of water traps). Furthermore, conventional completions do not handle effectivley heterogeneity or permeability contrasts exposed along the sand face. The ICD controls and interrogates more optimally both rock and fluid properties in the reservoir, hence delaying early water breakthrough. This early water breakthrough causes reduction in potential hydrocarbon recovery; the operation of the ICD is minimizing reserves left behind. If water breaks through in a well without ICD, these hydrocarbons are lost and cannot be drained subsequently. This paper covers the design and application of new open hole sand face completion architectures equipped with Inflow Control Device technology (first in Ecuador) in Block 15. The design and well preparation prior to completion operations and results are presented for two types of formations e.g. consolidated and non-consolidated. Detailed simulation models were performed and discussed with the Client prior to the drilling operations. The models are run using nodal analysis software and include the reservoir simulation grid. A-priori simulations explored several scenarios to address and compare different uncertainty issues, flow conditions, well rates and pressure drawdowns both in the pre-planning and final installation of the completion. The final design incorporates a removable housing ICD hardware, this allows on-site nozzle changes to create relevant delta P, to enhance well performance just after the well has been drilled and uses the real time data from the final logging operations. The real time logs were then evaluated while the well was drilled and used to refine the final simulation model prior to completion installation in the ground. The ICD completion architecture was successfully installed in consolidated sandstone and non-consolidated formations, with permeability varying from 250 mD to about 1D. The hydrocarbons viscosities varied from 5 cP, 8 cP, to 12 cP (consolidated sandstone, Well 1) and between 19 cP to 21 cP (non-consolidated formation, Well 2). Well 1 in the consolidated formation is flowing with equipment ESP and its initial production was about 4000 BOPD dry oil, currently the water cut raised slowly from 1.5% about 24%. Well 2 required well conditioning and performing as expected.The key advantage of using ICD is that it balances the flow across the entire horizontal section; delays early water breakthrough and uniform areal drainage. It is concluded that Inflow Control Device proven technology is beneficial and successful in Bloque 15, Ecuador and its application will be considered in other fields.
Completion with anchored guns instead of killing techniques have been used extensively in Ecuador since 2008, completing 111 works to date only in Block 15. During this process several continuous improvement practices as well as new completion techniques were implemented including:Job design improvements:Productivity improvements:• Significant reduction in both perforating and completion skins using static and dynamic underbalance.This paper shows different case studies of completion and perforating designs that enabled to reduce skin as well as completion time in Block 15. A new completion procedure using anchored guns with dual concentric completion is also described. Objectives• To show the new operational and completion design practices that enabled to reduce drilling rig time (monobore completion), completion time and perforating skin • To show the standard completion design that includes anchored guns as the current practice in new wells, reentries, dual concentric completions and low pressure sand reservoirs.
The objective of this paper is to describe a comprehensive approach integrating static and dynamic well characterization to optimize well completion and subsequent improving oil production in thin sand reservoirs.The following procedure was used to estimate and optimize the production potential of 3 feet sand reservoir located in Limoncocha Field:• Accurate well logging program to identify thin sands. (Vertical Resolution, Static Data) • Open Hole Mini DST program to estimate permeability, skin effect, and reservoir pressure and productivity index. (Dynamic Data) • Anchored guns with 800 psi of static underbalance to avoid control fluid invasion. • Well completion done with drilling rig; No well test is required using this methodology. • PVT sample taken in cased hole for further characterization and continuous improvement.
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