A considerable amount of hydrocarbon resource is estimated to remain in the ground even after primary and secondary recoveries in the fields.As of 2003, the estimated oil-in-place from the forty-seven producing fields in Malaysia stand at about 20.1 BSTB, with a cumulative production of 4.9 BSTB and reserves of 2.5 BSTB[1]. This translates to an averaged recovery factor of only 36.8 percent for producing fields in Malaysia.For this reason, the remaining oil-in-place of 12.7 BSTB i.e. 63.2% of STOIIP will be the prime target for Enhanced Oil Recovery (EOR) projects.On top of the value that could be gained through EOR applications, most of the fields are already entering maturing stage for primary and/or secondary depletion with declining oil rates and increasing water-cut and GOR trend. This situation will further merit the application of EOR processes.However, to date, there has been no full-field application of EOR in Malaysia, with the exception of a pilot WAG project in Dulang field[2, 3] and MEOR stimulation project in Bokor field[4–6]. In 2000, a screening study on seventy-two (72) reservoirs in Malaysia has identified almost a billion barrels of additional reserves that can be achieved through EOR.Majority of these potentials resides in a few major reservoirs, which carries about 60% of the total EOR potential7.The screening study has also identified several key EOR technologies that are most applicable in Malaysia, namely gas injection, chemical injection, and microbial.Thermal processes were investigated but have been ruled out due to the operational, properties of reservoir fluid, safety and commercial limitation of the methods for Malaysian offshore applications.However, transforming those potentials into real projects may face some challenges and change of operating philosophy.Factors such as facilities condition, sources of injection gas, reservoir characterization, technology applicability, and commercial aspects will play an important role in planning for an EOR projects in Malaysia. This paper presents the possible opportunities that could be realized by EOR applications, and discusses issues and challenges including change of mindsets required in making EOR a reality in Malaysia. Overview of Malaysian Oil and Gas History The earliest officially recorded oil find in Malaysia was made in July 1882 by the British Resident of the Baram district in Sarawak. The oil was used by the local residents for medicinal purposes and later for lighting lamps and waterproofing boats. Commercial exploitation of petroleum only began in 1910 when the Anglo-Saxon Petroleum Company, the forerunner of the present Sarawak Shell, which was granted the sole right to explore for petroleum in Sarawak, struck oil in the town of Miri, marking the start of the Malaysian petroleum industry. The Miri success encouraged further attempts to discover other onshore fields. However, only traces of petroleum were found, and these were not large enough to justify drilling activities. Consequently, by the 1950s, attention turned to the seas. This was made possible by new improvements in offshore petroleum technology. Marine seismic surveys were carried out for the first time in Sarawak in 1954. The shift offshore began to show results in 1962 with the discovery of oil in two areas offshore Sarawak. Other finds followed in rapid succession. In Peninsular Malaysia, petroleum exploration activities began in 1968 and the first oil field was discovered in 1971. As in many other developing countries, oil companies in Malaysia had been operating under what was known as a concession system. After the 1973 oil embargo, oil-producing countries of the world realize the importance of controlling their own petroleum resources.In Malaysia, it led to the promulgation of the Petroleum Development Act (PDA) in 1974 and the formation of a national oil company, PETRONAS, to ensure that the nation's petroleum resources could be developed in line with the needs and aspirations of the nation. PETRONAS, short for Petroliam Nasional Bhd, is wholly-owned by the Government, the corporation is vested with the entire oil and gas resources in Malaysia and is entrusted with the responsibility of developing and adding value to these resources.

PENGARUH JUMLAH CACING TANAH (Lumbricus rubellus) DAN WAKTU PENGOMPOSAN TERHADAP KANDUNGAN NPK LIMBAH MEDIA TANAM JAMUR TIRAM  SEBAGAI BAHAN AJAR BIOLOGI   Darwis Husain1, Sukarsono1, Nurul Mahmudati1 1Pendidikan Biologi FKIP Universtias Muhammadiyah Malang, e-mail : drw.darwishusain@gmail.com   ABSTRAK Penelitian ini bertujuan untuk  mengetahui adanya pengaruh jumlah cacing tanah dan waktu pengomposan terhadap kandungan NPK limbah media tanam jamur tiram, mengetahui kandungan NPK terbaik sesuai standar yang ditetapkan pemerintah yaitu N 0,4%, P 0,1% dan K 0,2% serta mengetahui penerapan hasil penelitian sebagai bahan ajar biologi. Jenis penelitian yang digunakan adalah True Experimental Research yang dilakukan pada tanggal 07 Juli-07 Agustus 2014 di Laboratorium Kimia Universitas Muhammadiyah Malang. Rancangan penelitian yang digunakan adalah Rancangan Acak Lengkap (RAL) Faktorial Design yang terdiri dari 2 faktor, faktor A merupakan jumlah cacing tanah (25, 30 dan 35 cacing) dan faktor B merupakan waktu pengomposan (5, 10 dan 15 hari). Analisis data menggunakan anava 2 jalan dan uji Duncan. Hasil penelitian menunjukkan bahwa jumlah cacing tanah 35 cacing dan waktu pengomposan 15 hari merupakan perlakuan terbaik. Persentasi unsur hara terbaik yang dihasilkan yaitu N (3,85 %), P (0,78 %) dan K (1,45 %). Sedangkan Rasio C/N yang dihasilkan yaitu 10,51.   Kata Kunci: Limbah, Cacing Tanah, Waktu, Pengomposan, Kandungan NPK

No abstract

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractA considerable amount of hydrocarbon resource is estimated to remain in the ground even after primary and secondary recoveries in the fields. As of 2003, the estimated oil-in-place from the forty-seven producing fields in Malaysia stand at about 20.1 BSTB, with a cumulative production of 4.9 BSTB and reserves of 2.5 BSTB 1 . This translates to an averaged recovery factor of only 36.8 percent for producing fields in Malaysia. For this reason, the remaining oil-in-place of 12.7 BSTB i.e. 63.2% of STOIIP will be the prime target for Enhanced Oil Recovery (EOR) projects. On top of the value that could be gained through EOR applications, most of the fields are already entering maturing stage for primary and/or secondary depletion with declining oil rates and increasing water-cut and GOR trend. This situation will further merit the application of EOR processes. However, to date, there has been no full-field application of EOR in Malaysia, with the exception of a pilot WAG project in Dulang field 2, 3 and MEOR stimulation project in Bokor field 4-6 .

This paper is a review of the gas fields development in Malaysia. The major subsurface engineering considerations for gas development include drive mechanism determination, well requirement, completion strategies, well deliverabilities, recovery factor and reservoir surveillance requirements. For surface engineering, the major considerations include offshore facilities function, platform configuration and sequence and process and compression requirements. The result of the review is the summary of some of the differences in gas fields development to date. Introduction The first gas field development in Malaysia started in 1982 when E-11 field, located offshore Sarawak, was developed. In the following years, four more gas fields namely Duyong, Jerneh, F-23 and F-6 were developed. The Duyong and Jerneh gas fields are located offshore Peninsular Malaysia while E-11, F-23 and F-6 fields are located offshore Sarawak (Figure 1). The fields are operated by PETRONAS Carigali Sendirian Berhad (PCSB), ESSO Production Malaysia Inc. (EPMl) and Sarawak SHELL Berhad (SSB), all are the PS Contractors to PETRONAS, the national oil company. In Peninsular Malaysia, the first development started in 1984 when Duyong field was developed by PCSB to provide the necessary offshore infrastructure for development of gas fields offshore Peninsular Malaysia. With the increasing demand for gas prompted by the onshore pipeline network installation by PETRONAS to fuel the power and industrial sector, sales from Jerneh, EPMI's first gas platform, was initiated in 1991. Gas demand is projected to continue to grow in the near future. To meet this growth, EPMI will develop another field, namely Lawit, for production in 1997. In addition, two gas reservoirs in existing producing oil fields were also developed in 1984. However, their development will not be discussed here. In Sarawak, E-11, being the closest to shore, was the first gas field developed by SSB. Delivery of gas to shore commenced in 1982. Shortly thereafter, in 1983 the second gas field F-23, came onstream. The third and the largest gas field, F-6, started production in 1987 Produced gas offshore Sarawak is delivered to Liquefied Natural Gas (LNG) plant and fertilizer plant. A small portion was used for power generation. Another LNG project is currently under construction and will commence operation in 1995. Development of gas fields dedicated for the second LNG project is currently in progress. This paper discusses the major subsurface and surface engineering considerations for gas fields development in Malaysia. It will also outline some of the differences in gas fields development to-date. GEOLOGY OF PRODUCING FIELDS In Peninsular Malaysia, hydrocarbon accumulations are found in the Upper Oligocene - Upper Miocene alluvial-coastal plain clastics. P. 549