This article, written by Assistant Technology Editor Karen Bybee, contains highlights of paper IPTC 12390, "Temana Field Pilot Implementation: A Shift in Sand Control Philosophy To Improve Well Performance," by Wan Amni Bt Wan Mohamad, SPE, Maharon Jadid, SPE, and Mahmoud A. Wahba, SPE, Petronas Carigali Sdn. Bhd., originally prepared for the 2008 International Petroleum Technology Conference, Kuala Lumpur, 3-5 December. The paper has not been peer reviewed. The Temana field consists of unconsolidated reservoirs that require active sand control. The conventional internal-gravel-packed (IGP) technique has been used widely because it has provided a reliable means of abating sand production. These completions, however, have skin factors greater than 15, which increases with time as a result of fines migration into the packed area. In many cases, flow efficiencies were reduced by 70%, which affected well performance severely. Introduction The Temana field was discovered in 1962 and brought on production in 1979. The field is approximately 19 miles west of Bintulu in a water depth of approximately 96 ft. It consists of three hydrocarbon accumulations, Temana west, Temana central, and Temana east. The field has undergone a complex tectonic history and is highly faulted and compartmentalized. The latest development is from the existing Platform A, which penetrates the Temana saddle, in the southeastern part of Temana central. The main reservoir target is the I-65 sand. The sand has a fining-upward log signature with a sharp base at the bottom of the sand. The sand contains light oil of approximately 41.1°API with reservoir pressure of 1,553 psi, average porosity of 26% (oil), and effective permeability of more than 1 darcy. The main drive mechanism of this reservoir is depletion drive, with weak-to-moderate aquifer support. There are seven existing platforms and two additional production-processing-facilities platforms. Approximately 44 out of 74 of the existing oil-producer wells were completed cased hole IGP, and only two wells had premium screens installed in horizontal open holes. On the basis of well-test data for these wells for a similar type of reservoir, the average skin is 10 to 15 and increases to 20 to 30 after several years of production. The average productivity indices (PIs) of these wells ranged between 1 to 20 bbl/(psi-D). Investigation shows that the increasing skin and deterioration in production are a result of fines movements into the gravel-packed sand, and this was aggravated when water broke through. Well-Design Considerations The best standalone screen (SAS) available in the market should be selected for the new Temana wells, considering economics and well deliverability. The well-design team developed a workable solution to be used to minimize various risks. The SAS proposed is the direct wire-wrapped screen (WWS), which is a surface-filtered screen, where plugging tendency is minimized.
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