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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).
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. This paper shows results from use of a new technology that uses in-well-conveyed fiber-optic distributed acoustic sensing (DAS) for the detection of sand-ingress zones across the reservoir section throughout the production period in real time.
In this paper, the authors describe a project to design, field trial, and qualify an alternative solution for real-time monitoring of the oil rim in carbonate reservoirs that overcomes these disadvantages. This paper shows results from use of a new technology that uses in-well-conveyed fiber-optic distributed acoustic sensing (DAS) for the detection of sand-ingress zones across the reservoir section throughout the production period in real time. This paper discusses the objectives of the Fiber-Optic Leak-Detection (FOLD) project, carried out in Verneuil-en-Halatte, France.
As part of an effort to evaluate existing riser systems, an operator launched an inspection and testing program to investigate risers retrieved following well abandonment after a service life of nearly 10 years in the Gulf of Mexico. New long-term contracts between offshore drillers and equipment makers reduce downtime and risks associated with key components, from blowout preventers to risers. This paper evaluates the feasibility of a number of production- and export-riser configurations for ultradeepwater applications. This paper presents results from full-scale testing of a flexible riser equipped with embedded sensors for distributed-temperature sensing (DTS).
The XamXung field offshore Sarawak, Malaysia, is a 47-year brownfield with thin remaining oil rims that have made field management challenging. The dynamic oil-rim movement has been a key subsurface uncertainty, particularly with the commencing of a redevelopment project. Supervisory control and data acquisition systems no longer simply monitor operations and produce large volumes of data in static displays, but now collect production data from all operation data sources and contextualize and present them to workers in real time as meaningful, actionable information.
The US Chemical Safety Board will investigate the blowout that killed three workers at a Chesapeake Energy well in central Texas. This paper focuses on the preparation for, and implementation of, well-control training, while highlighting the integration of people skills into curricula and what advantages operators and drilling contractors have obtained. Fiber-optic technologies—distributed temperature sensing and distributed acoustic sensing—have been experiencing an ever-increasing number of applications in the oil and gas industry as monitoring systems. This paper describes the mobilization of a snubbing unit and blowout preventer (BOP) stack in the Middle East that enabled a well with an underground blowout and surface broaching to be brought under control within a short time. The resignations come as the company makes downward revisions to its production guidance after a disappointing performance from its TEN and Jubilee fields offshore Ghana.
Fiber-optic technologies—distributed temperature sensing and distributed acoustic sensing—have been experiencing an ever-increasing number of applications in the oil and gas industry as monitoring systems. This paper covers the 7-year history of drilling-fluids application in a reservoir drilling campaign offshore Abu Dhabi, from the early use of a solids-free, brine-/water-based mud to the recent application of nondamaging, nonaqueous fluids (NAFs) with micronized acid-soluble ilmenite. This study focus on the design and evaluation of a customized water-based mud (NP-WBM) using silica oxide nanoparticles (SiO2-NPs) and graphene oxide nanoplatelets (GNPs). Recent research has put extensive focus on the magic of graphene in drilling fluids. Graphene, because of its thermal, electrical, chemical, and mechanical properties, improves mudcake stability and minimizes fluid loss that eventually reduces formation damage.
If you are not logged in, you will receive a confirmation email that you will need to click on to start receiving the newsletter. Layoffs have begun at Occidental Petroleum, which needs to slack costs after buying Anadarko, as well as Apache. ConocoPhillips’ one-of-a-kind test site in the Eagle Ford studied core, image logs, proppant tracer, distributed temperature sensing, distributed acoustic sensing, and pressure, which shows that not all hydraulic fractures are created equal. For the past 20 years, the diagnostic fracture injection test has been used across the frontlines of the shale revolution to paint a picture of what cannot be seen. However, that picture has not always been so clear in the eyes of subsurface engineers.
This paper presents the basic concepts and architecture of the Eni Reservoir Electromagnetic Mapping borehole electromagnetic mapping system that integrates borehole EM methodology with surface EM methods to provide real-time mapping of reservoir-fluid distribution during production or injection. An intelligent drilling optimization application performs as an adaptive autodriller. In the Marcellus Shale, ROP improved 61% and 39% and drilling performance, measured as hours on bottom, improved 25%. With their gee-whiz—albeit artificial—intelligence, robots may be the industry’s answer to jobs deemed dangerous, dirty, distant, or dull. A test showing that it’s possible to automate the billing process for produced water hauling has opened the door for tracking a wide range of field activities.
A novel automated workflow is presented for integrating fiber optic Distributed Temperature Sensing (DTS) data in Cyclic Steam Stimulation (CSS) reservoir simulations using a machine learning assisted history matching workflow. This study uses actual field data from a horizontal well CSS operation in a heavy oil field in California. The value of integrating DTS in the history matching process is illustrated as it allows the injection profile to be accurately estimated along the entire length of the well. Since the steam-oil relationship is the main driver for forecasting and decision making in thermal recovery operations, knowledge of downhole steam distribution across the well over time can decrease uncertainty in predictive modeling and optimize injection and production.
High resolution large DTS dataset is integrated in numerical simulations for estimating downhole steam injection profile, by utilizing machine learning techniques. A stepwise grid-refinement approach was implemented to optimize computational efficiency and improve predictive accuracy. A multi-segmented wellbore model enabled the distinction between the wellbore dynamics and the reservoir effects on the flowrate and temperature response. The proxy models created from statistical and machine learning techniques streamlined the workflow and also helped to quantify the uncertainty due to the reservoir heterogeneity. Particularly, the Design Exploration Controlled Evolution (DECE) optimization engine enabled the entire range of uncertainty to be captured by applying machine learning to history match the water, oil, and temperature profiles simultaneously. DECE algorithm's ability to handle a large number of parameters was particularly useful in incorporating grid refinement to account for small-scale heterogeneities such as localized hard streaks and interbedded shale. In effect, a more complete history match is achieved by incorporating both production and DTS data, and steam conformance is more rigorously assessed.
Visualization of the DTS thermal profiles through time also helped in identifying downhole issues in real-time. Particularly, thermal communication with another well was detected due to an unexpected increase in downhole temperatures in the test well. This also resulted in non-uniform reservoir heating and poor steam conformance. After the communicating well was worked over, an improved steam profile was observed from the DTS data. The continuous downhole monitoring using fiber optic surveillance made it possible to not just detect the thermal communication event in real-time, but also assess the effectiveness of the remedial workover, which could have been missed with conventional logging.