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Abstract Peninsular Malaysia Operations (PMO) plays an important role in supplying gas demand throughout the region since the gas business commencement in 1980's. Currently about 600 MMscfd gas is supplied by PMO. At the moment, three non-associated gas (NAG) fields, namely DYG, RSK, and TBC contribute to about 50% of the total gas supply from PMO. Apart from producing NAG, the RSK and DYG fields also serve as network hubs to evacuate gas to the Onshore Gas Terminal (OGT) through two independent gas delivery systems: Joint Delivery System (JDS) and Resak Delivery System (RDS) respectively. The two JDS and RDS gas streams are mixed at OGT and then delivered to the customer processing plant, with a CO2 maximum limit of 8% by mole. Apart from the many operational challenges to sustain gas production, meeting the gas specification proves to be a difficult task, especially for the RDS where TBC gas (with about 30–40% CO2) is to be blended with RSK gas (itself producing about 23% CO2).The TBC gas was put on stream in 2011 and an Acid Gas Removal System (AGRS) was deployed to reduce CO2 content. Prior and upon commissioning of the AGRS facility, feed of CO2 level into the gas network was managed by optimizing the flow rate. This paper describes some major challenges in sustaining the gas production supply and meeting the gas quality requirement. The major operational challenges include subsurface uncertainty and problems, maintaining gas compression reliability, AGRS operations and optimizing the usage of gas pipeline network. To complete the analysis, some commercial aspects are also discussed in the paper. Introduction This section consists of two parts:overview of gas business in Peninsular Malaysia andoverview on RSK/DYG field operations. The first part would be introducing the gas market in Peninsular as well as the strategy of fulfilling the gas demand. The second part would be describing the RSK/DYG field operations as the focus of this paper.

Pul-A field is an oil producing field located about 260 km offshore Terengganu, eastern Peninsular Malaysia in a water depth of about 77 meter in the South China Sea (Refer to Figure 1). The field is equipped with oil and gas processing plant, gas injection facilities and gas compression system. Pul-A was brought to production in March 1978 with an average oil production of 1,400 barrels oil per day (BOPD). The oil production peaked at around 35,000 BOPD in 1979. Previously produced water was treated using a corrugated plate interceptor (CPI) unit prior to discharge. The water treatment is required to ensure the effluent water quality is in compliance with regulatory effluent discharged water requirement of maximum oil content of 40 parts per million (ppm). The CPI unit was down several times in 2005 and 2006 causing twenty daysproduction deferment with an estimated opportunity loss of USD 6.8 Million. In line with the effort to maintain the oil production by flowing high water cut wells, a new produced water treatment technology was chosen to replace the existing CPI unit. The new equipment is a vertical separator that is equipped with acombination of induced gas and cyclonic fluid motion to improve solids, water and oil separation. Pul-A team successfully installed the new equipment with challenging modifications and tie-in work in aging facilities. The unit that was commissioned in October 2010is capable of treating produced water up to 15,000 barrel water per day (BWPD).

A Field is an offshore field located at offshore of Peninsular Malaysia, facilitated with an integrated oil and gas processing plant, water injection facilities and gas lift infrastructure. The field was brought to oil production in end of 2001 and achieved the peak production of about 120 Mbopd in 2005. In early of 2002, it started gas production at an initial rate of about 300 MMscf/d which is currently maintained at about 300–350 MMscf/d. The crude oil production peak was followed by a moderate decline over the next three years. Besides crude oil and gas production, the field also produces condensate as by product while producing gas. It was recognized that a proactive field management strategy was required in order to minimize any further production decline as the field production forecast showed a declining trend. Since A Field is one of major gas contributors, its gas production sustainability is very important to fulfill the gas demand in the region. The current gas sources in A Field are natural gas reservoir as the main source and the associated gas from oil production. It was recognized that subsurface and surface integrity is the key success for sustaining A Field gas production. The integration is important to ensure proper planning and execution for gas development within the A Field area as well as sustaining the crude oil production. There are several alternatives to maintain gas production. The analysis presented here describes the use of an integrated approach involving multi-disciplines to achieve the most suitable decision and maximize value creation focusing on A gas sustainability.

Peninsular Malaysia Operations (PMO) is one of three domestic regions of PETRONAS Carigali Sendirian Berhad (PCSB) located in offshore of Peninsular Malaysia. The operations cover six of main operation areas namely PPD-D, PPD-F, PPD-L, PPD-P, PPD-S and PPD-T. Those operation areas have a wide operation ranges: from green to brown fields, from single to multiple products, from onshore terminal to offshore Floating Storage and Offloading (FSO) and Floating Production Storage and Offloading (FPSO), from heavy crude to light crude and from big to small fields. PPD-D area is gas producer; PPD-F, PPD-L, PPD-P and PPD-S areas are crude and gas producers while PPD-T area is onshore crude and gas terminals. PPD-F area is scatter small fields facilitated with one unit of FPSO and one unit of FSO; PPD-L area is a big oil field facilitated with water alternating gas (WAG) injection facilities, gas lift infrastructure and one unit of FSO; PPD-P area is scatter medium to small brown oil and gas fields facilitated with processing plant, water injection facilities, gas compression, gas lift infrastructures, crude pipeline and gas pipeline and PPD-S areas is a big oil and gas fields, facilitated with integrated gas and oil processing plant, water injection facilities, gas lift infrastructure, crude pipeline and gas pipeline. In some oil fields, water injection is applied for reservoir pressure maintenance while water flooding and Enhanced Oil Recovery (EOR) technologies are implemented to maximize oil recovery. Some fields are still producing naturally while in most brown fields, gas lift is suitable to assist the crude production. Production operations comprises of three functions: production planning, field production operations and production logistics. The main scope is crude and gas production and evacuation from the well up to the terminal or exporting point. As the think tank in production operations, production planning consists of three functions: production analyst, field and integrated production planning and hydrocarbon accounting and allocation. In day to day works, production planning is focusing on crude and gas production achievement. Field production operation as the heart of production operations, handles day to day offshore routine activities, process performance improvement, process plant upgrade and new production facility installation. Considering the importance and urgency of capability building, production operations has taken significant measures in developing and helming competent engineers in order to achieve and maintain excellent production operations as well as to sustain technical talent development. Analysis presented in this paper describes important keys in competency development; they are 1) capability mapping, 2) skill development process and 3) measurement and feedback.