The fifty-two sandy and multilayer reservoir from depth 500 – 1750 m in Mamburungan field became more challenging when electric submersible pumps (ESP) were used. The average 2 – 7 m range net pay height in each layer contrasts with sand production for screen implementation in reducing productivity index. Multilayer reservoirs result requires various types of ESP design based on depth. As a result, a reliable method is needed to produce the well effectively and economically. The production method was divided into two basic concerns. Firstly, determining reservoir analysis with loose sand reservoir at 500 – 1000 m depth, and consolidated sand reservoir at 1000 -1750 m depth, Secondly, designing ESP which could accommodate all layers, which are divided into two main zones, i.e. the optimum design zone at 1200 – 1750 m depth and the overdesigned zone at 500 – 1200 m depth. In an overdesigned zone attention must be paid to choke installation to limit production rate, the safety factor for motor temperature specifications based on reservoir temperature, and also the safety factor for power specifications in variable speed drive (VSD) and transformer. Currently, all ESP wells in Mamburungan field are producing without failure and the ESP operation is running smoothly by implementing the aforementioned production method. In the optimum design zone, no ESP performance issues have been raised. Meanwhile in the overdesigned zone, potential performance issues might not be arise by adhering to certain rules: application of choke to control the production rate within up thrust and down thrust area; implementation of additional 40 percent safety factor in motor temperature specification refer to the deepest layer temperature; design of VSD and transformer to provide sufficient power consumption based on motor requirement at the deepest layer. Applying the overdesigned method delivers an optimum trade-off between lifetime, cumulative production, economic value with ESP system efficiency to produce the well in Mamburungan field.
Sembakung field was discovered in 1977 and is located in North East Kalimantan, Indonesia. From the reservoir point of view, hydrocarbon is produced from 32 layers of shallow (ranging 1500 -3500 ft TVD) TBL sandstone formation, which has discontinuous lenses reservoir characteristic with deltaic depositional environment. This environment caused a significant amount of very fine sand production that may be troublesome for most artificial lift types. The reservoir has initial pressure and temperature of 1249 psig and 180 F, with solution gas drive as the drive mechanism. This causes a sharp decline in reservoir pressure; hence the wells cannot flow naturally for a long time. The crude characteristic is ranging from 36-37API deg. and produces with a typical GOR of 150 -2,400 scf/stb. Sembakung is located in a remote and swampy area which can only be reached by air and river transportation. As a result, a special rig is required for drilling and workover which will be very costly to mobilize and to operate. Also, the wells must be developed in a cluster system (PAD), making a high inclination in trajectory to reach the target zone. During 30 years of operations, many types of artificial lift trial have been performed, such as electric submersible pump (ESP), rod pump (HPU) and hydraulic jet pump (HJP). Given that TBL sandstone formation has solid problem, rig mobilization and operations are very costly, high deviated well construction, so HJP became the obvious choice. Currently 43 active oil wells in Sembakung are producing with the aid of HJP as artificial lift, contributing 2,200 BOPD productions.The aim of this paper is to share the advantages, experiences, innovations and best practices of HJP application in a remote and marginal field, covering rig-less installation of HJP assembly with pump in (PI) and pump out (PO), production optimization by discharge pressure (DP) setting, well surveillance, solid handling options (such as dual vessel application, sand trap and special power fluid for severe sand problem), HJP configuration options, and comparison of surface pump (triplex vs centrifugal pump/HPS).
Having characteristic deltaic sandstone with 72 multilayer reservoirs with 252 perforation history became more challenging when determining potential zone. It is challenging because most of all have already produced. Regarding low oil price, high success rate on evaluating potential zones are needed. Developing an artificial intelligent (AI) to evaluate performance of potential zone based on perforation history and log evaluation could increase its success rate. Since log evaluation is used to determine potential zone, basic log evaluation parameter is used as input. There are also several zone characterizations to made AI more accurate such as; water zone, tight zone, and coal zone. Production history was used as an output and converted as 0–1. The output of this AI expected to predict cumulative production in one year in 0–1 index by iterated using Bournazel – Jeanson water breakthrough model to predict performance. Artificial Intelligent has been implemented while determining workover program. There are eight workover programs that have been executed. All of them give an expected result based on artificial intelligent prediction. Three programs has been executed and produced more than a year. The production performance created by artificial intelligence are quite match within actual performance.
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