Completion operation is one of the most important contributors to successful well deliverables. Without a proper design of the accessories and efficient operation in conveying the completion assembly, the true potential of a well may not be realized. Coiled Tubing Drilling (CTD) was first attempted in Peninsular Malaysia in February 2011 and the wells were designed to be completed as Coiled Tubing (CT) re-entry sidetrack using 2-3/8" pre-drilled liner and swell packers with maximum inclination of 90° angle and dogleg ranges between 30-60° per 100 feet. The liner and swell packer assembly were designed to be conveyed to the target zone via coiled tubing and to go through 3 ½" tubing with maximum clearance of 2.8" and dual casing exit from the existing completion setup. Apart from the small and rigid clearance, another challenges that the team faced was differential sticking due to mud property that was used to maintain hole stability and to prevent the hole from collapsing before the completion was placed. Since the completion would be conveyed through high dogleg environment, the type of liner and swell packer chosen had to able to withstand the bending stresses applied to it. A small error will result in parted assembly or inability for it to be conveyed all the way to the intended zone. This paper presents the challenges faced during the design and completion operations and discusses the program devised to overcome the above mentioned issues. Based on the lesson learnt from previous wells in which the operations were not 100% successful, the team made significant improvements in terms of mud property, swell packer design, procedure changes and introduction of friction reducer into the completion program of the final and last well of the campaign that finally enabled the liner to be conveyed to the total depth (TD) successfully.

The sustained and relatively high value of oil and natural gas has resulted in an unprecedented level of drilling activity and implementation of innovative methods to recover as much hydrocarbon as possible, and as quickly as possible. The resulting demand for conventional drilling rigs for programs has forced the rates high and the availability low, making use of the units difficult to justify for use in declining fields with less significant amounts of recoverable product. The by-passed reserves remaining accessible in these depleted fields exist in volumes worthy of pursuit, but must be done economically. In many fields, operators, either intentionally or unintentionally, bypass pay zones during initial development by focusing only on the best zones. Accessing bypassed thinly laminated formations can be economically attractive but poses several challenges, especially due to aged platforms and completion string in place, also offshore environment is adding its own challenges. Coiled Tubing Drilling (CTD) has yet to establish itself in an offshore environment. Numerous one-off projects have been tried, but commitment was never made to a number of wells to see through the learning curve and realize the potential of the application. Offshore South China Sea have a huge quantity of candidates on existing installations, installations that, due to water depths and sub sea conditions require large, expensive rigs to drill or re-enter wells. Technically the wells can be accessed with coiled tubing with drilling parameters seen regularly in other projects. The challenges for this pilot project will be equipment specification and set up, efficiently exiting the casing, and management of wellbore stability in open hole drilling and completion techniques. The main objective of this pilot project is to bring proven technology to offshore environment to access small bypassed reserves economically and provide an alternative to conventional drilling. The well candidates were selected with strict work scope to avoid going beyond the regular CTD application to ensure learning curve and lessons learned can be implemented throughout the project and achieve the objective. This paper will described the preparation, execution, achievement and lessons learned from this 4 wells pilot project in offshore South China Sea.

Cementing through coiled tubing electric line (CT e-line) is not a common practice; this application is highly recommended in Coiled Tubing Drilling (CTD) applications using the existing CT e-line pipe to achieve a better time performance for sidetracking a well since using the CTD technique is mainly based on economical evaluation. Several considerations need to be taken into account while designing the job and performing the operation. The relatively high density and viscosity fluid can lead to bird nesting the cable due to high friction and excessive slack inside the pipe; it can also affect the integrity of the cable as well as the performance of the bottomhole assembly (BHA). The interface between cement and other fluids pumped through CT e-line pipe can be also affected. A review on a feasibility study of cementing through CT e-line that was performed in 2003 in Alaska highlights all the concerns, challenges, and potential issues that can be encountered during a cementing job through CT e-line, best practices, lessons learned, and way forward to implement this technique. This review is supported by two successful case histories performed in Malaysia CTD campaign applying this technique for different objectives: remedial cementing for casing and tubing sealing in a deviated well and remedial cement plug for window recovery. By implementing cementing through CT e-line, the effective job time was improved by avoiding swapping pipes in an offshore environment where the logistic, safety, and space accommodation is a huge challenge. The use of CTD as an economical sidetracking technology was reinforced by making the CT e-line pipe universally utilized in all the project steps, even for running and setting completion.

Petronas Carigali Sdn Bhd (PCSB) had been using only Safe Working Load (SWL) as a guideline to lift the load of a container in the cargo lifting operation in Peninsular Malaysia Operations. The standard of practice which required only SWL visibly marked on the container, was used widely in offshore and onshore operations until the recent findings of the latest release of British Standard EN 12079:1999 which detail out a few more important piece of information that should be displayed on the container. The old practice required only SWL visibly marked and this practice had generated a lot of confusions among the personnel and crane operators that dealt with lifting activities. Furthermore, due to the lack of written standards and procedures, some of the containers were marked with either or both Maximum Gross Weight (MGW) and SWL. The crane operators had to use their own judgments to execute the lifting operation. Aside from that, safety was also at stake because a lot of the containers were poorly marked and missing other crucial information such as load test certification.Efforts were taken to correct this practice by strictly following the standards and proper documentations were prepared as a guideline to all personnel. The new BS 12079 requires all offshore containers to have a plate attached to the container that bears the information of serial number, MGW, tare mass, payload, certification number and design temperature. By having this information, the safety during cargo lifting operations was improved and personnel involved gained more comprehension of the lifting guidelines.This paper presents the lesson learnt regarding the disadvantages of the old practice and steps taken to improve the cargo lifting safety in PCSB by introducing and implementing the new BS 12079.

This paper presents a case history of a slickline propellant stimulation treatment performed in a well at the Penara and North Lukut field, which is a small oil field operated by PETRONAS Carigali offshore Peninsular Malaysia. The stimulation was performed using propellant that rapidly burns to create a high pressure gas pulse, which in turn breaks through damage in the perforation tunnels and near wellbore, effectively creating fractures through the damaged zone to enhance well productivity. The Penara and North Lukut reservoir pressure is around 3000psi with a bottom hole temperature of 258oF. The Crude has a medium gravity of 32 API, however it has a low GOR and high wax content with a tendency for heavy wax deposition. Frequent scraper runs are required to prevent excessive wax deposition in the low rate wells which have well head flowing temperatures below the wax cloud point temperature. Nowadays, slickline, due to its light weight, is widely used to perform well interventions and perforating operations on small platforms. Conventional CTU and E-line are often too heavy to be lifted on board by the platform cranes. Since field production start up in August 2004, slickline has been successfully used for well interventions to change out gas lift valves and to carry out regular tubing wax scraper runs. Slickline with 0.108"stainless steel wire was used to convey the propellant stimulation guns. Propellant simulation software was used to simulate the downhole pressure response to ensure that well integrity would not be compromised and to help select the optimum gun size. For each treatment one 10 foot, 2 inch OD gun was used. An additional unique feature of the tool string was the gun firing mechanism which utilized a coded sequence created from variation of surface jerking rate to generate its firing command, providing reliable and safe gun activation. Lastly, this paper also details the results of the propellant stimulation treatment which significantly enhanced the productivity of the treated well. Introduction The Penara and North Lukut field is located in the northeastern fringe of the Malay Basin in South East Asia, approximately 300 km offshore Terengganu, Malaysia in a water depth of 62 m and at the time of development was considered to be a marginal field. The field has been developed using two monopod platforms, one at Penara and one at North Lukud, both of a lightweight structural design (Figure 1) featuring an integrated deck and topsides concept connected via sub-sea pipelines to a Floating Production, Storage and Offloading (FPSO) vessel. The Penara reservoirs are of early miocene age deposited under fluvial environment with meandering stacked channel systems. The sands exhibit a fining upwards sequence of multiple stacked channels sands. The Penara well was initially drilled to target the I-65 oil sands. I-65 was however found to be wet with the well sidetracked twice. The two initial pilot holes were eventually plugged back and the well was completed with 3 ½ inch tubing as a single selective oil producer in 4 zones K-5, K-10, K-20.5 and K-50.1. (Figure 2) Based on open-hole logs obtained from Logging While Drilling operations, K-20.5 is an argillaceous sand with significant amounts of silt and clay content. It has a net to gross of 0.47 and a net pay of 7.3 m with average Sw of 47.18% and average porosity of 12.48%. The K-50.1 is a better quality reservoir with some silt and clay streaks. The net to gross is 0.92 while the total net pay is 20.3 m with average Sw of 56.42% and average porosity of 15.42%. K-20.5 and K-50.1 are separated by a shale break.