Developing reserves in the southern Negros, Philippines, requires the operator to drill through volcanic formations known for their abrasiveness and high unconfined compressive strength (UCS). Efficient penetration with conventional bits through the volcanic rock, which contains silicified andesitic tuff, breccia, quartz, chert, and pyrites, historically has been very challenging. Typically, when a bit encounters the hard formation, the strong impact exerted on the bit induces cutter damage, forcing a round trip of the BHA for a new bit. PDC bits have many advantages over roller cone bits and have outperformed them in many applications. However, in geothermal applications, roller cone has been performing better than PDC bits. Traditionally, it was believed that it impossible to drill this type of formation using conventional PDC bits. In an offset well, the operator chose to use a tungsten carbide insert (TCI) bit in an attempt to reduce bit consumption and trip time and to increase rate of penetration (ROP). However, postrun analysis shows that the offset well requires at least three TCI bits with and average meterage of 200 m at an ROP of 3.5 m/h. The bits were pulled out with broken cutters and graded with 5-8-LT-TQ, 4-7-WT-PR, and 7-8-WT-TD. To deliver a bit solution, a research initiative was launched to investigate new types of cutting elements. The project was successful and yielded an innovative conical diamond element (CDE). This element has twice the diamond thickness of conventional PDC cutters, resulting in higher impact strength and 25% more resistance toward abrasive wear. A new bit type was designed with the CDEs strategically placed across the bit face from gauge to the bit center utilizing a finite-element-analysis (FEA) -based modeling system. The placement of CDEs is mainly to support and protect the conventional PDC cutters from impact damage and to strengthen the overall cutting structure. Before the job commenced, engineers used an FEA-based modeling system to predict the bit performance in a virtual environment. The analysis was completed by comparing simulation results between drilling dynamics of a conventional PDC bit, TCI bit, and the new CDE bit. The simulation output indicated that the CDE bit is more suitable to drill the hard compact carbonate formation compared with the conventional PDC bit and TCI bit. The CDE bit appeared to be more stable and yielded significantly lower vibration at the bit and along the BHA. The 8½-in CDE bit was run and drilled the entire 8½-in hole section through the hard volcanic formation to TD at a significantly higher ROP compared with the offset well. Compared with the offset well that required three TCI bits to reach TD, the CDE bit delivered more drilled interval at a higher ROP while providing a smooth, high-quality wellbore, enabling casing to be set on the first attempt. Also, the dynamic response predicted by the modeling system matched the bit, BHA, and drillstring vibration profile recorded during the actual field run. Improvement in drilling performance for this particular run has saved the operator 10 days off their AFE.

Back then, communication between rig-site and town was a huge challenge, even in Malaysia where the first offshore drilling started in the 1960s. During those days, offshore rigs and platform seems isolated and communication was only done via phone call and fax machine which has resulted in very delayed information, and at some point, causes difficult decision making. However, as to date, real-time communication is no longer sounds alien to many people. In fact, it has become common terms that has been widely used in many other industries. With the emergence of sophisticated drilling software and a standard communication protocol, a real-time operation centre is typically occupied with multiple software with different function and capabilities to aid the drilling operation. Having an integrated real-time operation centre equipped with high technology software and coupled with subject matter experts in one room has often leads to efficiency and consistency while drilling especially when encountering complex drilling environment. This set-up has enable high level of collaboration starting from planning phase, drilling execution and post job phase, knowing that all domain experts' works from a single data source, where all decisions & modifications made are agreed upon. Pacing in this digital era, Oil and Gas operators and service providers now aims to embark on digital transformation to elevate their ability and agility to thrive in digital environment as an effort to be ahead of competitors. Having lots of data coming from various sources; leads this industry in this big data world. As technology is advancing at the speed of sound, the industry has now starting to talk about drilling automation, machine learning, artificial intelligence and big data analytics. To be able to do this, the people and the data itself must be ready for it, digitally and technically. This paper will talk about where we are now in regards with digitalization, explaining in detail how an integrated real time centre solution being deployed in operator's office together with the services provided and how we are preparing ourselves for digitalization to catch up with the fast pace of digitalization era.

PETRONAS has adopted drilling operation digitalization and formed real-time drilling operation center; which is also known as WELLS RTC since a decade ago, in conjunction with the company’s recent theme – Collaboration, Pace and Going Digital. Traditionally, a real-time drilling operation center has always been perceived as a monitoring center only for quick decision making to reduce Non-Productive Time (NPT). However, over the years the centre has evolved and not only has proven how the real-time operation center has allowed real – time problem solving, but it has actually brings so much additional value to the company as a whole. It has been the centre of drilling process and workflow efficiency transformation, the knowledge transfer and the collaborative discussion between multiple disciplines team that involved in drilling planning and operation. Prior to the existence of WELLS RTC, communications were made via emails and phone calls. Delayed decisions and miscommunication occurred along the way. WELLS RTC which operates 24/7 acts as collaboration center that provides avenue for the subject matter experts (SME) to discuss and make real time decision when needed. Collaboration & discussion is not confined to just Drilling Engineers, but includes and not limited to the Geological and Geophysical (G&G) team who are working on the well. Real-time data is now being stored in PETRONAS data center allowing the company to have full access to their own data. A direct impact of having a real-time operation center is the improved communication between each personnel who are involve in the drilling operation. Tough decisions are now easier to be made especially when the SMEs are sitting together under one roof looking at the real-time data transmitted from the rig site. Also, having full access to PETRONAS historical data allows the employee to search for the lesson learnt and best practices on the previous wells/fields allowing them to make more educated judgment (when needed) based on existing data. This data can be made available immediately for case study purposes. Software environments that are able to connect data between multiple servicing companies using the Wellsite Information Transfer Standard Mark Up Language (WITSML) format has resulted in increased accuracy of data communication which is needed for collaborative discussion. This paper will describe and explain the benefits of having a real-time drilling operation center via case studies studies on collaboration between multiple work groups contribute to the success of multiple drilling projects delivery and the technology used to setup this center.