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The addition of a hydrocarbon condensate to steam operations in heavy-oil and bitumen reservoirs has emerged as a potential technology to improve not only oil recovery but also energy efficiency. Thermal steam stimulation is considered the most effective of current methods for heavy-oil production. However, the method has problems with low coverage by steam injection and decreased efficiency.
The complete paper demonstrates the benefits of honoring data measurements from a multitude of potential sources to help engineers do a better job of including more diagnostics into routine operations to provide additional insight and result in improved models and completion designs. This paper updates a previous case study and presents the results of actual implementation of an optimized steam-injection plan based on the model framework. By measuring which tests best predicted the fractures observed at the Hydraulic Fracturing Test Site, Laredo Petroleum developed a method it hopes will improve fracture modeling in other places. In the complete paper, a new, fully coupled implicit tool was used to model an onshore Omani asset with multiple reservoirs, each featuring different fluids and multiple networks. The complete paper aims at a better understanding of the effect of channel content in complex fluvial channel systems on well-test-derivative responses.
This paper studies the technical and economic viability of this EOR technique in Eagle Ford shale reservoirs using natural gas injection, generally after some period of primary depletion, typically through long, hydraulically fractured horizontal-reach wells. The Eagle Ford formation has produced approximately 2 billion bbl of oil during the last 7 years, yet its potential may be even greater. Using improved oil-recovery (IOR) methods could result in billions of additional barrels of production.
The complete paper describes piloting the collection and analysis of distributed temperature and acoustic sensing (DTS and DAS, respectively) data to characterize flow-control-device (FCD) performance and help improve understanding of steam-assisted gravity drainage (SAGD) inflow distribution. A company is selling a new well testing tool designed to be a cheaper, simpler way to do fiber optic sensing, and then it fades away. With the availability of more-complex smart-well instrumentation, immediate evaluation of the well response is possible as changes in the reservoir or well occur. Mechanical-diversion techniques can ensure acid injection into the various intervals of naturally fractured reservoirs. This paper presents results from full-scale testing of a flexible riser equipped with embedded sensors for distributed-temperature sensing (DTS).
Its reward for years of struggling to adapt to low prices and weak demand for its oil and gas has been an epic crash. Canadians selling change say it is time to consider possibilities that seemed inconceivable in the past. So many unprecedented changes have occurred in the Canadian oil business that it is impossible to compare the current downturn to anything seen before. Steam-assisted gravity drainage (SAGD) performance in bitumen-recovery projects in Alberta is affected by geological deposits, reservoir quality, and operational experience. Although polymer flooding has become a promising enhanced oil recovery (EOR) technique, no field tests have been performed to date in Alaska’s underdeveloped heavy-oil reservoirs.
GlassPoint Solar was founded in 2008 to replace the use of natural gas for steamflooding heavy-oil reservoirs. But amid low energy prices, its chief investor has decided to pull the plug for good. This paper demonstrates how maintaining investment in high-quality 3D seismic during the last downturn, together with selective exploration, quality geoscience, application of new technologies, and efficiently maturing discoveries to early cash flow, was successful in sustaining future production. Field N is a complex heavy-oil field in the north of the Sultanate of Oman. The dynamic behavior of Field N is characterized by strong aquifer and is dominated by bottomwater drive.
Have Oil Sands Producers Found an On-Off Switch for Their Wells? When oil demand vaporized, oil sands producers cut 300,000 B/D of production from wells using steam injection to produce bitumen. It is a huge test of something they have long been reluctant to do—turn down in-situ production when prices plunge. Steam-assisted gravity drainage (SAGD) performance in bitumen-recovery projects in Alberta is affected by geological deposits, reservoir quality, and operational experience. The complete paper describes piloting the collection and analysis of distributed temperature and acoustic sensing (DTS and DAS, respectively) data to characterize flow-control-device (FCD) performance and help improve understanding of steam-assisted gravity drainage (SAGD) inflow distribution.