As you receive this issue of SPE Production & Operations, I hope you are
making plans to attend the 2006 SPE Annual Technical Conference and Exhibition,
to be held in the lovely city of San Antonio, Texas. The annual meeting
provides attendees the opportunity to observe firsthand the latest technologies
being developed for challenging deepwater offshore drilling, completion, and
production operations. In addition, the technologies currently in use onshore
or offshore are constantly being modified and adapted to meet new
This year’s technical sessions offer a chance to hear about the latest
advances and unique technical applications in one’s area of technical interest.
Furthermore, the meeting provides an opportunity to catch up with old friends
and make new ones and, best of all, to keep abreast of new technology.
As customary, the editorial committee for SPEPO will hold a meeting to
discuss the status of the journal and the issues related to providing the
readership with the latest technical information in a timely manner. These
meetings are often lively as we discuss the problems relating to the journal
and their possible solutions. I extend to you a personal invitation to join our
meeting and participate in formulating the future vision for SPEPO. Please
contact the SPE Technical Publications Dept. (firstname.lastname@example.org) or me
for meeting details.
Leading off this issue is a paper on acidizing: A New Effective
Stimulation Treatment for Long Horizontal Wells Drilled in Carbonate
Reservoirs discusses the effective stimulation of 45 horizontal wells with
openhole completions in two offshore fields in Saudi Arabia by use of a new
treatment system. The components of this new system include HCl acid and
The next paper, Stabilizing Wellbores in Unconsolidated, Clay-Laden
Formations, presents the results of laboratory and field testing performed
to determine the feasibility and effectiveness of applying a one-component,
low-viscosity consolidation material to stabilize the unconsolidated formation
sand surrounding a wellbore and to overcome the effects of cyclic loading while
minimizing the permeability reduction.
The effect of water cut on sand production has been an area of interest for
a number of years, and several mechanisms have been proposed to explain the
effect. Effect of Water Cut on Sand Production—An Experimental Study
presents the results of a series of laboratory perforation-collapse tests
designed to quantify the effect of water cut on perforation failure and the
resulting sand production.
The next paper, The Key to Predicting Emulsion Stability: Solid
Content, presents a method for quantifying the factors governing the
emulsion stability by coupling the standard bottle-test results with
corresponding crude-oil analytical data. Furthermore, statistical analysis by
means of partition trees produces emulsion-stability descriptions.
Oil/Water Separation Experience From a Large Oil Field presents the
results of a comprehensive study initiated to understand the main causes of
emulsion formation in the field and ways to optimize oil/water separation. Many
lessons learned from this study are applicable to any crude-oil-treating
Hydrocarbon production from well clusters, in which several wells flow into
one subsea flowline, often requires flow control for each well. Knowing the
actual performance of manifold chokes is of vital importance for optimum
production. Critical and Subcritical Oil/Gas/Water Mass Flow Rate
Experiments and Predictions for Chokes presents a predictive model based on
a a large database on critical and subcritical flow through orifice- and
cage-type chokes. The data were obtained by use of the multiphase flow loop.
The model appears to be best model in predicting the mass flow rate through the
orifice- and cage-choke geometries. A comparison with other models is presented
The development of unstable flow in multiphase pipelines is a major and
expensive problem for the oil and gas industry. Irregular flow results in poor
oil/water separation and limits the production capacity. Modeling of Severe
Slug and Slug Control With OLGA presents a model of the physical process
that generates slug. The model has been verified against the experimental data.
Several control strategies have been tested on the model, and results are
The next paper, Well Surveillance With a Permanent Downhole Multiphase
Flowmeter, presents field-test results of a new type of downhole multiphase
flowmeter. The results confirm the value of permanent downhole metering. Well
performance and its evaluation are some of the most important functions of
The Dimensionless Productivity Index as a General Approach to Well
Evaluation presents a general approach to well evaluation by employing the
field-derived, dimensionless productivity index, which is calculated from
measured information that includes production rate, reservoir and flowing
pressures, and well and reservoir data.
The paper Optimization of Riser Design and Drill Centers With a Coupled
Reservoir and Facility-Network Model for Deepwater Agbami presents a tool
and methodology for better modeling of the well-to-riser flow and the
optimization of rise count and configuration.
And, finally, we have a Discussion of A Practical Method for Anticipating
Asphaltene Problems and one of the original authors' responses to the
discussion. These articles present thoughtful consideration of a previously
published SPE paper and the original author’s response to those considerations.
SPE encourages discussions of this nature because it stimulates and promotes
the learning environment. In fact, the new online version of each SPE journal
has a discussion forum in which you can post your thoughts on each paper
published in a particular issue. For more information, refer to www.spe.org. As
ever, if you have any comments—positive or negative—about the content of this
issue, I encourage you to send them to me at email@example.com. Do not forget to
register for this year’s SPE Annual Technical Conference and Exhibition in
September. Happy reading!
The Acknowledgment section of Aron Behr et al.’s “Consideration of a Damaged
Zone in a Tight Gas Reservoir Model With Hydraulically Fractured Well,” paper
82298, which appeared in the May 2006 issue of SPE Production &
Operations contained an incorrect company affiliation. The corrected
acknowledgment is included here:
The authors would like to thank the German Soc. for Petroleum and Coal
Science and Technology for organizing and funding this work. We particularly
appreciate the help from the participating companies: the Gaz de France
[formerly Preussag Energie (Lingen)], Wintershall AG (Kassel), RWE DEA
(Hamburg), Erdöl-Erdgas GmbH (Berlin), and ExxonMobil Production Deutschland
GmbH [formerly BEB (Hannover)].
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