Water injection is an essential part of brown oilfield development plan both of pressure maintenance or water production management. The high cost and often tight economic margins associated with injection wells capacity require that the chosen stimulation technique not only provides an effective result to maximize injection well capacity but also carries an acceptable risk in term of the project cost and safety. Many well known techniques, such as fracturing and matrix acidizing have been developed over the years to achieve this result and are common in most water injection well operations. The objective of this paper is to show a new approach of stimulation technique can be maximized both of injection capacity and cut operational cost Dilation Cyclic Breakdown is a breakthrough stimulation technique through hydraulic treatment by injected high volume of formation water into the reservoir below tensile stress and above shear stress. The primary design that have led to these technique include the following steps : Certain criteria were used for pilot well such as hall plot and single well of nodal analysis. Operation can be performed by rigless operation and no chemical additive needed, equipment selection is approached by 3D fracture simulator both surface pressure and injection rate correlated to mechanical earth model syntethic. Pumping schedule and the number of cycle is optimized by pressure calibration analysis during Breakdown test, Step Rate Test and decline pressure analysis. It was critical that Step Rate Test and decline pressure analysis procedure be performed to determine fracture gradient as upper bound pressure and shear gradient as lower bound pressure. Various procedures were used in handling data recorded. Injection and pressure data from each well were plotted to observe the trend in the rate - pressure relationship. Nine injection wells were stimulated during 2020 - 2021. It has been an attractive result both of cut operational cost and increase injection capabilities. The operational cost per well can be reduced to $ 46,000 or 72% cheaper than matrix acidizing stimulation and the total incremental injection rate reach to 14,907 Bwipd or 1,656.3 Bwipd per well. A half of those injection wells were previously stimulated by matrix acidzing method but has not yet improved significantly. In addition, this method is also applied for two oil producer wells in sandstone reservoir as a pilot test. The increasing of Productivity Index greater 6.5 - 8x than initial as a result and has still been observed. Furthermore, this paper should be beneficial to all engineers currently working in brown and marginal Oil Field with tight economic margins to increase the production.

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This paper presents an integrated and simplified method with some field cases that can be applied to delay rapid production depletion and it focuses on the occurrences of the potential bypassed oil zone. The method that we used in here is by combining geological approach, with reservoir production history map as a result of data obtained during infill drilling and subsequent well work activities in the wells in the aim to get the remaining potential of reservoir. The primary benefit is to extent the field life as long as possible before it become a Marginal Field. Well services are the common ways in maintaining production in every field, in this case Sengata Field. This aging onshore field has been developed by PT PERTAMINA EP since 1973 and the production reached its peak of 6000 BOPD in 1979 and with average decline rate of 60%, the field is on a fast declining trend. Like many other deltaic environment reservoirs in the world, the structures of this field is extremely sophisticated and consist of large number of reservoirs and most of them are thin bed reservoir and multiple stacked channels that contain oil, gas and formation water. The observed drive mechanisms consists of a combination of Solution Gas Drive and Water Drive The complicated geometry is a serious challenge for engineers who are responsible for determining lateral and vertical communication between the individual sand units. Recent analytical method has been proven very successful in sustaining and revitalizing production shown by the oil increment up to 110% for it's target and allows PERTAMINA EP to optimize and prolong the field life.