This paper discusses the PLT-correlated results of two test wells completed during 2006; one in sandstone and one in a carbonate reservoir, with the new completion technology of nozzle-based passive inflow control devices (ICD) which improves performance of wells with reservoir challenges as described:In highly productive sandstone reservoirs, horizontal wells suffer from uneven flow profile and subsequent premature cresting/coning effects. In general, there is a tendency to produce more at the heel than at the toe of horizontal wells, which contributes to poor well cleanup at the toe. Additionally, excessively increasing the rate and/or horizontal well length can increase the risk of limiting sweep efficiency, resulting in bypassed reserves1.In carbonate reservoirs, permeability variations and fractures can cause uneven inflow profile and accelerate water and gas breakthroughs. Wells with early gas or water breakthrough have to be shut-in until remedial plans are decided and implemented, resulting in deferred production. The main reservoir objectives for applying passive ICD technology in the two test wells are:Sandstone: Decrease the influence of heel-toe effects and high permeability zones; hereby deferring water/gas breakthrough, improving well cleanup and sweep efficiency.Carbonate: Control flow rates from high permeability intervals and to limit production from each compartment based on lateral offset from the gas-oil contact to prevent premature gas breakthrough. The test well PLT-logs were correlated to static reservoir simulations. Analyses of the well performances show that the objectives of both completions were achieved. By having proper matches of the completions with ICD, the value over standard completions can be evaluated. Post-evaluation of the completion designs based on the PLT-log results has increased our understanding of the nozzle-based ICD performance. As a result several approaches for completing wells in both sandstone and carbonate reservoirs with ICD have been recommended in order to achieve optimized inflow performance. Introduction Two trial wells with nozzle-based passive ICD systems were designed and completed in 2006; one for sandstone and one for carbonate reservoirs. To evaluate and approve the new ICD completion, these wells were production logged and the results were carefully analyzed. The most important feature of the ICD completion is the self-adjusting effect of flow variations anywhere along the well trajectory and whenever they occur during entire well life. The key benefits are:Increased well life and reserves due to improved sweep efficiency.Delayed gas and water breakthrough.Decreased water/gas rates after breakthrough when water/gas mobility is higher than oil.Improved well cleanup.

This paper presents an innovative completion technology, fine tuned by reservoir simulations, for balancing the water injection profile into various sand formation zones in an open-hole completed injector well, increasing sweep efficiency. Traditional injection wells often suffer from the risk of sanding in, hence sand control is beneficial or even required. Another major challenge is to achieve even distribution of the injected water into all zones along the well-bore. Injector wells are often designed to penetrate, and give pressure support to, several reservoir intervals with various permeabilities which challenges the reservoir management. Permeability contrasts, heel-toe effect, formation damage, creation of thief fractures and well bore injectivity changes need to be managed to avoid early breakthrough in adjacent production wells. Smart-well systems are highly complex and costly, and for this particular case, where raw seawater is used, the high corrosion resistance requirement was considered a show stopper. The solution was to qualify and install special screens with integrated flow control devices, tailor-made for injection wells, and with correct nozzle sizes for this particular case. These screens were made of materials selected to withstand the corrosive environment and high rate of unfiltered water during lifetime of the well. The screens where gravel-packed to restrict annular flow and give zonal isolation, which optimizes regulation of reservoir heterogeneities. This new technology is representing a quantum leap forward in field economics, by marrying all the benefits realized with this simple robust and reliable self-regulating injection management system. The paper will discuss the qualification program inclusive focus on risk of erosion, plugging and corrosion. Further, the completion design of the well, with flow distribution simulations and sensitivities inclusive comparisons with actual field date is also reviewed together with economic value analysis. Future potential, applications and scenarios will also be discussed. Introduction Urd was developed as a satellite to Norne FPSO during 2004–2005. The oil field consists of two separate structures, Svale and Stær, located 4 and 9 km from the main field. The field was put on production in 2005 and was developed with 3 subsea templates, and pipelines for oil production, water injection and gas lift (Figure 1). Norne and Urd is operated by Statoil on behalf of ENI Norge AS Norsk Hydro Production AS and Petoro AS. The application of the special screens with integrated flow control devices for injection wells (called ICD injector) was evaluated as a part of the field development plan for Urd. Since both Svale and Stær consist of heterogeneous pay zone, the main reservoir management goals of implementing an ICD injector are: The important feature of the ICD injector is the self-regulating effect with functions independently of surface control. If one zone is fractured during the operation of the injector and can take more water, then the nozzle in the ICD injector will prevent increased injection into this fracture. This will ensure improved water distribution, which will result in better pressure support and drainage of the oil reserves in all zones.

TX 75083-3836, U.S.A., fax 01-972-952-9435.Post-evaluation of the completion designs based on the PLT-log results has increased our understanding of the nozzle-based ICD performance. As a result several approaches for completing wells in both sandstone and carbonate reservoirs with ICD have been recommended in order to achieve optimized inflow performance.

A preliminary investigation is presented on the use of Inflow/Injection Control Devices (ICDs) to control steam placement in the early stages of a Steam Assisted Gravity Drainage (SAGD) process. The two parts of this process that are examined are the steam circulation period and the early stages of injection/production in which the steam chamber is beginning to form. A SAGD case study has been designed that accurately models the initial circulation period in which both wells circulate steam in order to conductively and, to a lesser extent, convectively heat the region around the well pair in order to establish communication after which both wells switch to injection and production. Flow control is examined in a variety of configurations in the steam injection well, the devices being placed to control steam/water flow along the tubing, along the annulus and from the tubing to the annulus.

The paper covers the application of new technology drilling and completions equipment in horizontal wells to maximize production and recovery in a thin oil rim reservoir. The parallel process applied to the engineering design, drilling and completion operations, real-time decisions, and results are presented. As part of the second stage development of a mature oil field offshore Malaysia, a shallow target was identified. Initial engineering and reservoir studies suggested that three deviated wells or two horizontal wells would be required to develop the area. While the horizontal wells option was expected to have lower costs, the well construction was far more technically challenging. To ensure maximum production and recovery a 2,000ft lateral section was required, further detailed studies indicated that for the long lateral to be successful, well placement with respect to reservoir boundaries and fluid contacts, and open-hole sand screens of a high mechanical integrity would be critical. Additionally, in order to ensure even oil production and limit early water and gas production In-flow Control Devices (ICD) would be required as part of the completion. The well was actively steered using a Rotary Steerable System (RSS), and Logging While Drilling (LWD) measurements including a deep azimuthal resistivity distance to boundary device. Drilling was very efficient with the well placed close to the top of the sand, avoiding shale contact that could cause screen plugging, and the required distance from fluid contacts. The Real-Time (RT) logs were used to select optimum settings for the adjustable ICD completion prior to running in hole. The completion was run without incident and when the well was placed on line, produced without water breakthrough and without requiring gas lift due to effective clean-up of the entire horizontal section. Production from the well has exceeded expectations and is currently over double that of traditional wells. The application of advanced well placement technology and field adjustable ICD completions has enabled the economic development a small area of remaining hydrocarbon in a mature field, while maximizing production and recoverable reserves. Even with the increased technology cost, the overall project cost was 15% less than if standard well construction techniques had been applied. The accurate placement of the wellbore close to the upper shale and even production along the lateral due to the ICD completion has resulted in a more efficient reservoir sweep increasing recoverable reserves by ~100 MSTB.