The scale of the problem of earthen pits in Kuwait—millions of barrels—together with a variable content of the sludge makes for a challenging task.
The Sultanate of Oman is blessed with oil, but much of that oil is heavy. Oman has experienced a drop in crude production over the past six years to 737,700 bopd in 2006 from 956,000 bopd in 2001. For the first five months of 2007, production continued dropping to an average 713,000 bopd. The average Omani well produces about 400 bopd. This situation creates a problem for the treasury, since some 40% of the country’s GDP comes from oil. The government has acted and has put in motion several EOR projects to bring major heavy oil reserves into production. In 2005, Occidental Petroleum was granted a PSC to steam flood Mukhaizna field. Other fields being developed with EOR processes include Fahud, Harweel, Marmul and Qarn Alam. Mukhaizna field covers more than 40 mi2 and holds reserves of over 2 billion bbl of original-oil-in-place.
Iraq shows the greatest promise among Middle Eastern producers for adding significant reserves and production.
After watching output from one well drop to zero, Kuwait Oil Co. used a customized multi-frac job to bring it back to life.
Implementation reduced the number of days to drill a well from almost 100 to below 60 in Saih Rawl field, Oman.
The Arab Gas Pipeline Project is a cooperative success
Intelligently completed MRC wells have improved Aramco's development economics.
Higher oil prices have contributed to greater economic growth, and inflation is also on the rise. Productive capacity is growing, but slowly.
In addition to expanding oil and gas output, new discoveries have been made.
PDO combined technologies to unlock the potential of Oman's mature fields.
Compared to a conventional completion, a Saudi Aramco maximum reservoir contact well with intelligent well systems succeeded with minimal incremental risk.
Demand flattens, giving producers time to expand capacity
IEA's World Energy Outlook 2006 has significant methodology flaws
Knowing the composition of the gas is important in designing an effective gas lift system.
More than 40% of horizontal wells encounter major unexpected structural geologic/ stratigraphic changes during drilling that result in wells being sidetracked or serious consideration given to this option. As the hole angle increases and measured depth of bed thickness becomes more distorted, correlation between predicted and actual geologies proportionately increases in difficulty. Therefore, real-time correlation must be systematically planned in advance, and must identify key marker beds and decision points. Failure to recognize individual parameters within the reservoir of interest, such as stratigraphy, rock type, reservoir geometry and structure, fluid content, and formation petrophysical properties, can result in costly mistakes. As witnessed during planning and executing horizontal drilling programs in the Hawiyah and Haradh fields of Saudi Arabia, the industry’s ability to drill horizontal and high-angle boreholes has improved with the aid of proper geological planning, execution and evaluation.
Successful application of multilaterals and intelligent well systems by Petroleum Development Oman onshore shows that the technology is not just meant for deepwater subsea wells.
An integrated solution uses reservoir surveillance and intelligent wells to reduce uncertainties about compartmentalization, deliverability and vertical communication.
When drilling ERD wells, one should determine the criteria for choosing between a motor/variable gauge stabilizer combination and an RSS.