fax 01-972-952-9435. AbstractWater cones largely dictate oil recovery in a typical bottom-water situation. Major parameters influencing coning include mobility ratio, producing rate, completion interval, and anisotropy. We conducted a systematic study to understand the influence of these and other parameters on coning. Our aim was to develop producing and completion rules for managing the Greater Burgan's Third Middle Sand (3MS) reservoir in Kuwait.The building blocks of our study were: (1) detailed geologic modeling using core and openhole log data, (2) geostatistical modeling for 3D sector modeling, (3) transient-pressure testing, (4) production logs, and (5) cased-hole saturation logs. Singlewell, 2D radial models were built to understand various elements of coning for existing completions. We also explored alternative completions to mitigate coning. The study included the use of single-and dual-lateral wells and cone-reversal techniques. Follow up studies using a 3D-sector model confirmed some of the findings of single-well modeling.Results show that high anisotropy provides near piston-like displacement and, consequently, completing at the top of the bed appears prudent in a vertical well. High producing rate tends to leave higher remaining oil saturation than those do at moderate rates. A combination of high-anisotropy and low-length-tothickness ratio makes horizontal completions unattractive in the crestal area of the field.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractNumerous case studies substantiate the merit of horizontal drilling, especially in coning situations. Nonetheless, the burning question remains: do horizontal wells assure performance optimization in all cases? This paper explores the effectiveness of horizontal wells in a high-permeability (k h > 3,000 md), high-anisotropy (k v /k h < 0.01) Burgan Third Middle Sand (3MS) reservoir in Kuwait. To do so we built a sector model containing 35 wells to match 50-year history in a strong edge-water-drive system. With the history-matched model, we examined performance of horizontal wells under various scenarios. These scenarios included reservoir and completion considerations, such tubing size, well length, and high-slant configuration. For comparison, we measured the performance of a horizontal well against its vertical counterpart in terms of water-breakthrough time, oil acceleration, and incremental recovery.Results show that horizontal wells do not appear to offer any decisive advantage over their vertical counterparts in terms of breakthrough time and ultimate recovery. That is because unique reservoir characteristics, such as highanisotropy (k v /k h ) and low-length-to-thickness (L/h) ratios, coupled with high productivity index (PI), all contributed adversely to horizontal wells' performance when compared with vertical wells. Horizontal wells' PI may be higher but the vertical well is equal to the task of delivering desired oil rates, although with a somewhat larger drawdown. In essence, the primary constraint on well performance is the tubing size, not PI. Therefore, a well with large tubing will achieve optimal performance, regardless of its orientation in the 3MS reservoir.
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