fax 01-972-952-9435. AbstractWell control can be an unpleasant experience. In its initial stages the problem often appears unconquerable and weeks can pass without progress.This paper is about the successful abandonment of such an episode of well control, in deepwater (i.e. greater than 300 m water depth), that was initially suspended with a closed-in subsea BOP. The BOP held in place a sheared 5-in. drillpipe that had been intermittently blowing dry gas and formation cuttings to the rig floor for 20 days.The objective of the well-recovery operations was to reenter the well and properly abandon it without creating another uncontrolled situation. All operations were to be conducted in compliance with HSE protocols.It was paramount to have total control of the well at all times necessitating two BOP stacks. This contingency resulted in the suspension of a heavy load on the seabed, subject to excessive bending moments during bad weather. The well head arrangement was essential but the time loss caused by weather conditions was becoming intolerable. New and innovative plans made during the well-control operations cut 3 to 4 weeks of uninterrupted operation down to 5 days of operation. Cementing under pressure was the key abandoning solution. Several scenarios were drawn up for this eventuality and this paper elaborates on the decisions, choices, and solutions made during the final abandonment operation.

TX 75083-3836 U.S.A., fax 1.972.952.9435. AbstractThe following-up of drilling operations in "real time" from a remote location has been on the wish list of some drillers for quite a long time. In recent years, this has become a reality with phenomenal advances in digital technologies, satellite communications, remotely controlled systems, and collaboration centers that allow locations in different parts of the world to follow up on an operation on a round-the-clock basis.The primary objective for the exploration drilling of oil and gas wells is to find and develop new energy sources that can meet the energy demands of the future. It is also universally accepted that this objective must be met safely and efficiently.Real-time operations go a long way toward ensuring safety for the oilfield; the ability to remotely monitor operations avoids the need for experts or other non-essential people on location. This reduces the exposure risks associated with travel or rigsite presence for a number of people. The safety factor extends beyond the physical transportation or presence of individuals at a work location because, by monitoring subsurface pore pressure trends, shallow flow hazards can be detected early and a recourse taken. The well is essentially under the discernible watch of several experts at critical points ensuring the delivery of a safe and efficient well.Several other operational benefits can be realized from real-time operations. This paper discusses several of the tangible gains realized from this type of operation and the future it holds for its users.

TX 75083-3836 U.S.A., fax 1.972.952.9435. AbstractThe following-up of drilling operations in "real time" from a remote location has been on the wish list of some drillers for quite a long time. In recent years, this has become a reality with phenomenal advances in digital technologies, satellite communications, remotely controlled systems, and collaboration centers that allow locations in different parts of the world to follow up on an operation on a round-the-clock basis.The primary objective for the exploration drilling of oil and gas wells is to find and develop new energy sources that can meet the energy demands of the future. It is also universally accepted that this objective must be met safely and efficiently.Real-time operations go a long way toward ensuring safety for the oilfield; the ability to remotely monitor operations avoids the need for experts or other non-essential people on location. This reduces the exposure risks associated with travel or rigsite presence for a number of people. The safety factor extends beyond the physical transportation or presence of individuals at a work location because, by monitoring subsurface pore pressure trends, shallow flow hazards can be detected early and a recourse taken. The well is essentially under the discernible watch of several experts at critical points ensuring the delivery of a safe and efficient well.Several other operational benefits can be realized from real-time operations. This paper discusses several of the tangible gains realized from this type of operation and the future it holds for its users.

TX 75083-3836, U.S.A., fax +1-972-952-9435. AbstractOne of the critical measures of success in matrix acidizing is to get the acid distributed across all the zones of interest, thus ensuring they are all stimulated and maximum production is achieved. Because most producing zones are not homogeneous in terms of permeability, porosity, water saturation, or the degree of damage they have experienced, uniform distribution of acid during the acid job is seldom achieved. This task is further complicated when high water-saturation zones form part of the pay interval; not only do the producing zones get inadequate stimulation but the water zones get preferentially stimulated to produce large quantities of unwanted water that can kill the well or increase the lifting and disposal costs for the well.Many acid-diversion techniques, mechanical and chemical, are available to help achieve even distribution of acid, but addressing water control and stimulation of the preferred zones in one treatment is uncommon. A new acid-diversion technique using associate polymer technology (APT) applied in the western-desert region of Egypt achieved tremendous results when compared to similar wells treated in the area. In one case, the production results from the well treated with APT were as high as 5,000 BFPD with negligible (0.02%) water cut compared to another well that produced similar fluid quantities, but with more than 50% water cut.This paper discusses the first use of APT technology in the Al-Amein dolomite reservoir of Egypt and compares it with the earlier uses of other diverting methods in the same field. Acid-job simulation results obtained from a matrix-acid job simulator is also presented to demonstrate the ability to design such jobs before execution and to optimize the placement technique and the choice of stimulation fluids for a reservoir.

The Issaran field, a heavy oil reservoir with estimated original oil in place (OOIP) of approximately 1.6 billion bbl of oil, was discovered in 1981. The producing horizons are the carbonate formations of Miocene age occurring from depths of 1,000 to 2,000 ft. The oil is of 9 to 12 °API with viscosity of 4000 cP at standard conditions. It was not until early 2000, after the crude oil prices rose to favorable levels, that a concerted effort was made to develop this heavy oil. Cold production from the fractured carbonate Nukhul reservoir (depth approximately 2,000 ft) was first targeted and the production from the field increased from 170 barrels of oil per day (BOPD) in 1998 to more than 2,300 BOPD in 2002. However, the Upper Dolomite reservoir, at a depth of 1,000 ft, held more than 50% of the OOIP, but did not produce.Subsequently, a pilot project using cyclic steam injection was implemented on two openhole completions in the Dolomite reservoir and the production results far exceeded predictions, proving it to be commercially viable. This pilot scheme was expanded to two, seven-spot pattern wells and the total combined production from the Issaran field reached 5,000 BOPD in late 2008. Recently, however, the productivity of the Upper Dolomite wells has declined. The water cut has increased and the steam injection efficiency is becoming questionable.Because the steam temperatures of nearly 600°F exceed the operational limits of conventional production logging tools (PLTs), they cannot be used for steam injection profile monitoring. In addition, wellhead control and operational safety concerns become challenging issues. One effective solution to the problem was to run high temperature Memory PLT (MPLT). These tools are built for high temperature service and can be run on slickline, making this a more cost effective solution. The three wells selected for the preliminary run of the MPLT service were also the first applications of this technology in the Middle East area.The primary results have already shown deficiencies in the steam injection process because most of the steam is being preferentially injected into water-bearing zones. This paper provides a detailed review of the results from the PLT surveys and the completion strategy implemented to improve productivity and maintain project profitability.