ANALYSIS AND STRATEGIC DECISION OF RIGLESS WELL CONTROL UNIT TO GET OPTIMUM CYCLE TIME IN DAMAI FIELD

• Main Author: Perdana Putera, Rizki
• Format: Theses
• Language: Indonesia
• Subjects: Manajemen umum
• Online Access: https://digilib.itb.ac.id/gdl/view/46936
• Institution: Institut Teknologi Bandung

One of the major oil field producers in Indonesia is Damai field. Damai field oil characteristic is heavy and viscous oil. Steam flood injection is critical to ensure the oil was liquefied and able to be transported from the well via pump and pipeline. However, one of the downsides of steam injection is the well become hot and it becomes difficult to kill well before the rig coming in. The rig needs to kill the well first to ensure no flow to the surface and perform the job in that well. Because of the difficulty to kill well, there are additional processes needed before rig can move into the location. The business issue is the additional activity creating longer well down cycle time. The longer well down and not producing oil, the more operator suffer loss both from financial and oil productivity. The current average well down period is about 20 days and the company target well down period is 7 days. There are many factors contributes to long well down cycle time such as workers, equipment, well condition, communication, program, etc. The project started by identifying the process using the swim lane diagram. The root cause was evaluated using current reality tree based on interview and observation. There are eight root causes that contributes to long well down cycle time but this project will only be focused on 3 main root causes of the problem: many unnecessary wells inputted into WCT schedule, there are several types of well need cooling job, misalignment between rig and rigless schedule. All other 5 root causes are out of scope of this project due to several reasons. The research method is evaluating cooling down equipment effectiveness for multiple type of well in Damai, evaluating cycle time per activity to determine the current optimum capacity, apply cooling down team selection criteria. Based on the study, there new well selection criteria for cooling unit is made to ensure the cooling unit are assigned to proper well type and the job is effective. The current ratio of rigless and rig (2-unit rigless with 1-unit rig) is not optimum and the rigless activity become the blocking activity. The optimum ratio of rigless and rig is 3:1 based on the cycle time analysis. There is also opportunity to improve cooling down unit work acceptance criteria to slightly higher pressure from 0 psi to 10 psi. This new approach will save the cooling down unit time meanwhile still ensuring rig can continue the job afterwards. The Kepner-Tregoe method is also chosen as a tool to support decision making about cooling down team acceptance criteria The next action plan is to communicate the study and recommendation to all stakeholder and get the endorsement from management. Estimated the improvement will resulted in decrease of well down period to from 20 days to 12 days with additional benefit $4,254,120/year.