Coiled tubing has been widely used worldwide to perform perforating and zonal isolation operation due to the ability in intervening highly deviated and long section of horizontal wells under live condition, where slickline and E-line have difficulties. This paper presents case history of coiled tubing perforating and zonal isolation evolution in infill well at Resak field, one of the gas field operated by Malaysia National E&P Company, Petronas Carigali Sdn Bhd. Since the beginning of Resak Field production, coiled tubing has been used to perforate numbers of infill wells with low success ratio. The reservoir characteristics with high formation pressure and BHT followed by high CO2, H2S production and improper well clean up contributed in the increase of operational risks and challenges. Several failures reported in the past was carefully analyzed to determine the actual root cause prior to coming up with the proper job design and operational procedures. CTU with 1.5″ CT reel was used to convey 140 ft of 2–7/8″ gun due to crane and platform deck loading limitation. The small CT size and large gun conveyance required extra precaution since the presence of gun shock during perforation may affect the CT integrity. Therefore supporting perforating software was run in advanced to optimize gun selection where both operational risks and production objectives were taken into consideration. Coiled tubing forces simulation was also used to determine the ability of the gun assemblies to be safely conveyed into the target sands. In addition to that, one of the unique features from the gun assemblies was the selection of electronic firing head over a conventional or standard drop ball mechanism. This tool utilized coded sequence created fromvariation of surface pump rate to generate its firing command, providing reliable gun activation where as the drop ball mechanism in the past was found to have some operational difficulties. Lastly, this paper also mentions the proper selection of zonal isolation method that can withstand the wellbore condition, providing adequate isolation whilst able to be retrieved for future production requirements. The result of those engineering studies managed to overcome the operational failures in the past and at the same time was able to meet the production objective. Project Result After performing the coiled tubing operation by isolating J10.2 with inflatable bridge plug and perforating J10.1 with deep penetration gun, the well managed to be produced at 22.7 MMSCF/D & stabilized at 48 MMCSF/D (23 % choke size) with total gain of 41MMSCF/D which was higher than the expected gain of 35 MMSCF/day (Figure 1). Currently the well is the highest producing well in Resak field with stable production at 49.8 MMSCCF/D. Introduction This gas producer well was drilled in March 2004 and completed in 4–1/2″ monobore completion by penetrating the reservoir of J-10.2 & J-10.1, with J-10.2 being perforated leaving J-10.1 un-perforated (Figure 2). Based on the log analysis, J-10.2 sand has 6.8m TVD net pay with average effective porosity of 15% and permeability of 26md followed by water saturation of 37.7%. After 2 years of production, gas rates started to decline from 18 MMSCF/D down to 7 MMSCF/D with gradual increase in water gas ratio up to 10 BBL/MMSCF. This phenomenon was also supported by adjacent well performance which was shut in due to high water production. Nitrogen lift operation was performed on adjacent wells, but failed to sustain the production. Despite the decline trend, remaining gas reserves are still attractive and having potential to be produced in the future at 85% recovery factor.

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Sotong-A9 was drilled in dual completion. Maximum target production is 3000 bbl/d for the long string while short string capable to produce 20 mmscd. Sotong platform was the highest producer for MASA field located about 135 km offshore Terengganu which comprises of Malong, Anding and Sotong. Currently all the produced oil and gas is process and store on FPSO facilities located nearby. During completion stages an "unknown" fish was left in hole thus hindering wireline intervention to open SSD to unload zone below the fish depth. Total potential reserve for both zones is estimate 20 million barrel of oil. Due to that, wireline operation to retrieve the fish was considered critical due of fear for leaving the zone with completion fluid can damages the formation. There were 2 wells included in the infill drilling campaign. Any delay due to fishing job can contribute to higher rig cost. Prior to actual job execution, few main challenges need to properly addressed such as job coordination/people management, well pressure control and slickline equipment rig up complexity. Therefore, while the drilling continue in Stg-03 well, slickline intervention for fishing operation was continue at well Stg-09L with the 21–1/4" conductor BOP still attached on it. Slickline lubricator is rig-up on top of the existing BOP prior to fishing job and pressure test was carried out to ensure the well pressure containment. This novel technique contributed to cost saving of USD 400K due to no requirement for rig standby for conductor BOP removal. This paper discussed on best practices of rig up wireline in existing drilling BOP, Job Hazard Analysis (JHA), job procedures and lesson learned. Introduction Sotong is a part of integrated marginal field development called MASA which also comprised Malong and Anding fields. Crude and gas are processed at nearby FPSO called Perintis. Same like its adjacent field, Sotong platform was built following small and remote platform philosophy; small deck space and very small crane capability. Thus, for the whole drilling campaign, rig crane is the only equipment that can be depended on for any lifting operation. Sotong infill drilling was planned to complete Sotong-A9 and Sotong-A3 as dual completions. Sotong-A9 was the first well to be completed prior to Sotong-A3 and the target completion for both wells was about 2 months. Sotong-A9L was drilled to drain K2 - K 7.2 and L sand, in which production target was about 3000 bbl per day. Satisfied with the first oil from the well, drilling team decided to start drilling Sotong-A3 as per original plan and left 21 ¼" conductors blowout preventer (BOP) still attached to wellhead area to save rig time.

Stabilitas peternakan unggas di Indonesia salah satunya dipengaruhi oleh ketergantungan bahan baku impor yang kuantitas dan harganya dinamis. Pendekatan yang dapat dilakukan yakni memanfaatkan pakan lokal yang mampu menyeimbangi protein dalam pakan tersebut. Penelitian ini bertujuan untuk menganalisis perbedaan antara biaya pakan lokal dengan pakan pabrikan yang diberikan pada ternak ayam KUB. Pemeliharaan ayam dilaksanakan pada bulan Oktober hingga Desember 2022 di kandang pemeliharaan ayam KUB Politani Pangkep. Data secara deskriptif dengan dua perlakuan yakni pakan pabrikan PT Charoen Pokphand (P1) dan pakan lokal (P2). Parameter yang diamati adalah penggunaan biaya dan pendapatan dari kedua perlakuan. Materi yang digunakan dalam penelitian ini adalah 100 ekor DOC ayam KUB yang dipelihara selama 1 periode (8 pekan) pada kandang litter free range.  Hasil penelitian memerlihatkan total biaya yang dikeluarkan pada P1 dan P2 secara berturut turut adalah Rp. 1.962.719 (P1) dan Rp. 1.527.100 (P2). Penerimaan hasil penjualan ternak sebesar Rp. 2.760.000 (P1) dan Rp. 1.527.000 (P2), sehingga diperoleh pendapatan antara P1 dan P2 masing-masing Rp. 797.281 dan Rp. 497.900. Berdasarkan data yang diperoleh dapat disimpulkan penggunaan pakan pabrikan memerlukan biaya yang lebih tinggi dibandingkan pakan lokal, namun memberikan pendapatan yang lebih tinggi dibandingkan P2. Hal ini disebabkan tingginya harga tawar berdasarkan bobot badan ternak yang diperoleh.

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