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This course develops strategies for completing horizontal wells. It covers both cased-hole and open-hole configurations, either with or without sand control. Participants will learn the applications and dynamics of horizontal wells, including drill-in fluids, hole displacement, cementing, perforating, and stimulation. They will also learn the guidelines for selecting stand-alone screens and executing horizontal gravel packs. Horizontal drilling was a step-change in the industry, but the technology is more expensive and riskier than drilling vertical or deviated wells.
Extended Reach Drilling (ERD) wells has broadened its historical definition from having MD/TVD ratio of 2:1 to include wells with horizontal departure of up to 25,000 feet or more. In this workshop, we will be making an economic comparison between extended reach wells and conventional lower deviated departure, while emphasising on highlights and lowlights of drilling ERD wells. Moreover, our discussions will indicate the correlation among various components involved in ERD wells, which include the design and interaction of special equipment, liner design, tubulars, and introduction of new technologies. Furthermore, how drilling and completion fluids design are key factors in the construction of ERD wells. Hence, continuous development of advanced software modules for hydraulics and hole-cleaning plays a fundamental role in the success of ERD wells.
The exploration and development of challenging reservoirs is now standard practice for Oil and Gas Operating Companies worldwide. Consequently, economic drivers to maximise the potential of unconventional plays have spurred significant advances in extended reach drilling. Specialised completions and intervention materials and techniques continue to support the safe production from highly corrosive sour fields, historically beyond the limits. Applying these advanced methods to redevelop mature fields has also proven to be a cost-effective strategy, enhancing oil recovery to levels previously unattainable. This 2-day workshop will discuss a variety of novel technologies and techniques employed to meet the objectives of safe and efficient well intervention, and address many unique operational challenges faced across the Middle East Region.
Petrophysical evaluation of well log data has always been crucial for identification and assessment of hydrocarbon bearing zones. Reservoir quality is defined by using petrophysical analyses coupled with petrographic observations, capillary pressure, and diagenetic studies, in addition to unconventional logs such as borehole images, nuclear magnetic resonance logs, elemental spectroscopy measurements, and spectral GR interpretation. This session will give a complete methodology and workflow for using all available petrophysical data to evaluate LQR.
The effectiveness of delivering information about a new energy project to community stakeholders varies based on the method used; how a message is framed can affect individual opinions. Models were developed for these wells for future water-production prediction and a spatial analysis was also conducted. This article explores the outlook for the global market and gives insight into technology trends and the regions that hold the biggest opportunities for water treatment.
Many methods exist for forecasting the production rate from unconventional reservoirs, but all have limitations. Recently, several publications have appeared relating the expected ultimate recovery (EUR) to the initial rate or the cumulative production after 3, 6, or 24 months. In the complete paper, these publications are reviewed, and their learnings extended, to several unconventional reservoirs. Work in 2018 studied 147 MFHWs covering many formations in the Permian Basin and a wide range of input variables and determined EUR using rate transient analysis, numerical simulation, and decline-curve analysis. The authors of that work compared the EUR with various cumulative production intervals (3, 6, 12, and 24 months) and concluded that the correlation with 3 months was poor; 24 months’ cumulative production was an accurate predictor of EUR but was not considered to be an early-enough predictor.
The Troll field is one of the largest gas producers discovered off Norway, but ensuring its long-term future required finding ways to drill wells in an increasingly fragile formation to develop its rich oil reserves. Statoil, operating the Troll field in the Norwegian sector of the North Sea, wished to run a deep sidetrack from the main bore in a multilateral well that would exit through the liner in the reservoir.
This paper compares the performance of three mature-field horizontal infill wells, one of which is completed with autonomous inflow-control devices (AICDs). Several designs for autonomous inflow-control devices (AICDs) are available. The comparative properties and abilities of these designs are the focus of this paper.
The complete paper documents the development, laboratory- and field testing, and lessons learned from a project to evaluate coated centralizers. In horizontal and extended-reach wells in which long completions are run into highly deviated or lateral zones, large compression loads arise because of running friction.