Well and Inflow Performance Relationship, termed TPR and IPR, respectively have been the unfailing methods to predict well performance. It is further to determine the schemes on optimising production. The main intention of the study is to explore TPR and IPR under heating treatment for heavy oil well. Klamono is a mature field which mostly has depleted wells, it produces heavy oil within 18.5 o API (>0.95 g/cc oil density), and therefore, artificial lifting method is necessary. Sucker Road Pump (SRP) and Electrical Submersible Pump (ESP) are the most deployed artificial lifting method in this reservoir. To boost the heavy oil production, the application of Electric Downhole Heater (EDH) in Well KLO-X1 is being studied. Whole Klamono's production is more than 100,000 blpd within 97-99% water cut. By installing EDH, oil viscosity is decreased hence oil mobility ratio will play a role to decrease water cut. EDH is installed together with the tubing joint to simplify its application in the wellbore. The study shows that EDH application can elevate fluid (mixed oil and brine) temperature. Oil viscosity confirms a reduction from 68 to 46 cP. The gross well production is up to 12.2 bopd due optimising its outflow performance and reducing 97.5 to 96.9% water cut. The field data gives an incremental of 4.9 bopd. The computational results only show an attainment of net oil production up to 8.3 bopd (2 bopd incremental). The EDH works to lessen both density and viscosity as we hypothesised for the mechanism of thermally induced oil production improvement. The evaluation study on its economics aspect exhibits good result that is 1.4 USD/bbl additional profit margin according to field data despite the challenging annual rig rent cost. Following the field data, the expected net income through analytical model revealed that this project is financially promising.

Offshore North West Java (ONWJ) field has been producing since 1971 with multi-stacked layers, solution gas to weak water drive mechanism, most of wells are completed with dual strings and gas-lifted. This condition compromise a relatively shallow top packer placement. In some cases, abandonment pressure has been reached as characterized by low static liquid level below deepest gas-lift mandrel. Apart from that, tubing integrity is becoming important issue as fields are maturing. Less operational complexity for the installation of siphon string or velocity string to tackle the two challenges above and better economic returns make it a better option compared to recompletion. The applied strings are from 1.75″ QT-900 coiled tubing, installed with various configurations of packer, gas-lift mandrel, and length depending upon wellbore completion, artificial-lift concern and well integrity requirement. Siphon string has been installed in 6 strings; whereby 3 strings with tubing integrity issue (well A, B and C), 3 strings with liquid level below deepest gas-lift injection mandrel (W, Y and Z). After installation, well A and B were flowing for 2 years before they were finally shut-in due to leak below the siphon string assembly. Well C had flowed for another 6 years before it was shut-in. Well X has been flowing since the inception of siphon string in 2006 until this paper is written, well Y has flowed for 8 years and well Z has been flowing for 1 year. An increase of 0.5% – 2% of recovery factors for these wells has created opportunity for other similar wells to continue or increase production. The first part of the paper will describe on the candidate selection and well configuration, the second part of the part will cover the installation procedures, challenges and lessons learnt. Finally, production results comparison from pre and post installation is presented.

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