Zawtika field, Block M9, Myanmar offshore is one of the gas fields that has been developed and been producing since 2013. Two types of well designs have been selected and drilled from platforms; Monobore (Tubingless completion, Gulf of Thailand technique) and Sand control well (cased hole gravel pack). Over the course of production operation many challenges and difficulties have been encountered; one of which is sand production resulting in excessive corrosion and damages to the surface facility and shorten the well life. Hence, sand control completion has been chosen as the main design for field development. During 2013-2014 Zawtika M9 Phase1A sand control wells were drilled with a drilling rig and later completed completion with a 2nd unit hydraulic workover. Though this strategy could bring a well to production soonest, it comes with additional cost and risks; mobilization, stand by, wait on weather, overheads, etc. Up to now, Zawtika M9 Phase1B for sustainable gas production delivery, previous strategy has been adapted for more cost effective operation during an ongoing oil price crisis starting 2014. "One rig strategy" has been implemented with a tender assist drilling rig (TADR). The strategy is to drill all required wells on the platform, then to convert the drilling rig to completion mode and to run sand control completion. Drilling rig has large deck space, high deck load capacity and capability to accommodate 170 people, and sand control equipment can be installed permanently on drilling rig without major impact to drilling operation. The key completion personnel onboard shall relentlessly prepare and commission equipment to perform completion operation right after drilling operation is completed. Ultimately drilling rig can be converted from drilling to completion mode within 3-5 days, compared with a 15 days move of 2nd unit per platform. With this strategy, risk exposure to heavy lift and marine operation reduce significantly. In fact the unpredicted rig stand by due to bad weather in Zawtika M9 Phase1A becomes manageable due to lesser number of rig moves. Sand control completion has been operated efficiently by using rig equipment, space and experienced crews. Many offline operations and activities can be performed concurrently, e.g. cement bond evaluation, wellbore cleanout, packer installation with wire-line, rack back tubular capability, etc. Likewise the drilling rig performance can be continuously optimized and improved. This also eventually extends to running speed enhancement, non-productive time mitigation by proven equipment and crews. With this strategy, the rig has so far completed 3 platforms in Zawtika M9 Phase1B with significant improvement and remarkable record. The total drilling and completion well duration has significantly decreased from Phase1A 18 days to 10 days in Phase1B. Therefore, millions of cost reduction and saving from "One Rig Strategy" claimed.

The Company's digital transformation project was started in 2018 to overcome the challenge from digital disruption, energy transition and hydrocarbon reserves declination. Drilling and well engineering cluster is a key player in operating cost optimization which requires digestion and analysis of tons of data generated through daily operational reports. Thus, several digitalization projects have been initiated to optimize drilling and well process to be better, faster, and safer. In this paper, we intend to share a successful journey of digitalization under drilling and well cluster. The transformation journey started with identifying engineer's pain points in each process, among which the most common were redundant processes, manual data inputs/calculations, and time spent on collecting and analyzing unstructured data sources. Moreover, diversified practices on engineering programs and data analysis adversely affect well design standardization and optimizations. To counter those pain points, digital transformation projects were ideated by using digital solutions and technology which are grouped in 5 focus areas: centralized data platform, business intelligence, robotic process automation, digital assistant, and data analytics from fundamental to advance level respectively. Besides out-of-the-box solutions, many internally developed systems have been utilized throughout the journey which helps engineers to build their digital capability and awareness. There are over twenty (20) drilling and well digital projects implemented since the transformation project has been started. And as a result, engineers’ workload has been reduced significantly using digital solutions such as data extraction, visualization, and in-depth analysis. For example, the first successful project under robotic process automation utilizes text analytic and Artificial Intelligence (AI) techniques to analyze well conditions and integrity status from unstructured data and to generate reports within a limited timeframe. Another successful case is well design automated workflow which saved around 40% planning cycle time and provides a better design quality which will lead to a lower well cost. Total cost saving of over 40 mmusd has been recorded so far under the digital transformation project. Furthermore, there is an outlook for additional cost-saving through future new projects, integration, and scaling up plans across the company's international assets. The results and outcomes are very promising to this point. We believe that these initiatives will help the company to improve productivity, benefits, agility, and move beyond business disruptions. Combination of drilling and well expertise with digital transformation solutions will significantly improve well design process, quality and operational efficiency which make industry stay competitive and resilient in the future.

The operator relentlessly thrives for the minimum well construction cost. Continuous improvement and Innovative approach are the major drives for developing the marginal gas field, Myanmar offshore. Whereas, routine and consistent operations may mask up the operator and leave out many rooms for improvement from operation excellence during the development phase of the project life cycle. PTTEPI successfully started up the second development campaign, Myanmar offshore in early 2016. Since then the team has brought up many ideas to continuously improve the operation and achieve milestones for both safety and performance. This paper will share the best in class for well construction of Myanmar offshore on well design, drilling engineering, rig selection, offline utilization, drilling and sand control practices and fit for purpose procedures. The performance is significantly improved on both drilling and sand control operation which results in total days per well reduction over 50% and 80% for drilling operation and sand control operation respectively. Total days per well for drilling performance on the last platform in 2019 is reduced to 4 days per well compared to 9 days per well when the first development platform was drilled in 2013. Sand Control performance is improved further. Total days per well for Sand Control performance on the last platform in 2019 is reduced to 3.5 days per well (dual-zone completion) compared to 18 days per well when the first development platform was completed in 2013. Recommended practices and well designs are shared as a case study of drilling and sand control operation for Myanmar offshore development. This can be a guideline for another operator to develop oil and gas field offshore Myanmar.

Drilling engineers use several applications to perform well design tasks and to create a final report for review and approval, any changes in subsurface information require revalidation of engineering calculations and repeat of the entire tasks to update the stage-gate report. This is usually a manual, timeconsuming and human error prone process that may result in additional cost and/or prolonged planning cycle time. Moreover, such manual works by individual engineers lead to diversified well design practices and formats across a company which make it difficult for standardization and compliance control. Drilling engineering computer programs are primarily standalone applications that are used for engineering calculations with no continuous workflow in most cases. Well Delivery Process (WDP) is an engineering software solution developed to integrate, automate and standardize well construction planning process across the operating company. The system encompasses several integrated workflows by which users can carry out drilling/completion tasks from feasibility study to concept selection and detailed design as well as operations monitoring and closeout reports on a single digital platform. Furthermore, functions such as engineering calculations, rules validation, offset analyzing, well schematic, risk analysis, checklist, and well program are automated through the workflows and several microservices built on a series of applications. The WDP, based on the company's well design automation initiative, was developed jointly with the service provider using its Business Process Management (BPM) tools. The system integration transforms how wells are constructed and delivered by combining a digitalized planning and design process with engineering models on a single and open cloud-native platform. Several tools and techniques such as design templates, continuous calculations, well cost models, etc. are utilized through integrated workflows to automate well design and process. The solution supports all new wells and leverage data from existing wells to optimize well construction process. As a result, the collaborative well design platform and automation tools take the drilling engineering process to the next level with a better quality well design and a reduced planning time.

As a part of the company's digitalization project, the Well Delivery Process (WDP) software solution was successfully developed and launched in early 2021. By using this solution, engineers benefit from the project objectives like process standardization, well design quality, and well planning cycle time reduction. The WDP software consists of a series of integrated well delivery workflows including well design, drilling execution monitoring, and closeout reports within a single cloud-based platform. The system also provides users with many automation features such as well design rules validation, offset well analysis, risk analysis, automated calculations, and digital reports (drilling programs). Through this paper, we share our experiences and observations on the system development and implementation, and also challenges and limitations that we faced to roll it out successfully. In our conventional practices before the digital transformation, drilling engineers had their individual practices/formats to perform the well delivery process using various applications and techniques. Computer applications were used to generate and compile a drilling program, but there was no standard way of performing this process. In situations where the design parameters and/or subsurface information change, engineers should have repeated the entire process to revise the design and/or the drilling program manually. To standardize the process, minimize repetitive tasks, and provide engineers with all required digital tools, the first solution (a prototype computer program) was developed in-house to prove the concept. After multiple peer reviews and trials, we used the prototype program to specify user requirements for generating the WDP software solution. An agile methodology was utilized to engage all drilling engineers in each sprint of the WDP development phase to ensure that their requirements are fulfilled. Upon completion of the development phase, a comprehensive User Acceptance Test (UAT) was conducted followed by training sessions before the cut-off date for switching from the manual process to the WDP digital workflow. Switching from existing practice to a new way of work is always challenging especially when it comes to introducing new software. There was some resistance at the start-up period due to users' unfamiliarity with the software and also software bugs that were not found during testing periods and UAT. A support team was set up to ensure immediate action on users' requirements and any technical issues with the software. During the challenging transition period, all users were fully supported until make sure they are enough familiar with the system to complete the task effectively. The support team deployed hotfixes (bug fixing) as quickly as possible with no major impact on the drilling programs' timeline, monitored the system performance on daily basis, and gathered feedback for further improvements. At present, the WDP is the primary system used by all drilling engineers in the company's domestic assets as an integrated end-to-end well delivery workflow that provides an improved design quality in a shorter planning time. More than 200 well design workflows have been initiated and approved through the system since it is being used. Based on the recent users' satisfaction survey and feedback, an overall rating of 4.2 from 5 shows the WDP solution's effectiveness with many popular and useful features especially offset well analyzer and well design dashboards. As one of the first end-to-end workflow generations in the drilling engineering process, the WDP could save the working time up to 35-40% (voted by users) through a centralized dataset platform and its holistic approach to process standardization/automation. Besides design quality and cycle time improvement, the system also enables advanced data analytics for further automation and enhancements.