# 1 Executive summary

PKM has commissioned Austar Gas Pty ltd to provide a resource estimate for its interest in the Prisma Kampung Minyak (KM) asset in Indonesia. The evaluation was performed in February 2017 using the updated field production data until 31st December 2016 and technical information provided by PKM.

On 15th July 2011, a 15-year production enhancement contract (KM KSO contract) was signed for KM field in Indonesia between Pertamina and Prisma Kampung Minyak companies. Kampung Minyak was later acquired by PKM and thus PKM is entitled to receive 25% of any extra oil production above the baseline oil forecast after cost recovery.

KM Oilfield was discovered in 1896 and has a producing area of 45 square kilometres. The field is located approximately 200 km south of Palembang City in South Sumatra Island, Indonesia. There are nearly 330 vertical wells in this area and 30 wells online in 2016 with oil production. During the development, operators have tried technologies such as water reinjection and hydraulic fracturing to advance field production. However, despite success from some of the water injection trials, oil production remained in a low level due to lack of proper understanding of reservoirs and inconsistency in water injection. PKM has started a work program since the start of its contract to enhance oil production by drilling new injectors/producers and recompletion (water shut-off, artificial lift design) of key old producers.

Detailed Geophysical and petrophysical studies on the existing seismic data and log correlations over KM field has divided the KM field into 9 separate blocks from north west to south east. The entire KM field appears to be affected by faulting and has a limited reservoir continuity between the blocks.

There are two main geological formations present in the KM field, the Muara Enim Formation and the Air Benakat Formations. KM has an original estimate of approximately 65.92 million barrels of original oil in place (OOIP) which are mainly located in Muara Enim Formation (named as STC to S7 layers) with a depth range from 90m to about 470m. Reservoir layers in Muara Enim Formation are channel sand bodies belong to water delta and generally have good thickness and reservoir properties. Muara Enim Formation contains layers with varying thickness (up to 12m) and has an average porosity of 28% with permeability ranging from 50 to 120md. Air Benakat Formation consists of deeper formations (S8 to S13) with poor reservoir properties. Among those, layer S8 has been productive with some production history and it has been included to the main package for the contingent resource estimate. Productivity and reservoir characteristic of layers S9-S13 are yet to be confirmed through further production testing and technology trials.

API gravity is ranging from 35 to 45 which suggests that KM oil is a good quality. A constant formation volume factor of 1.15 was used for all zones as reported by PKM. There is also very small amount of gas produced which is not normally measured by the company. The average porosity in Muara Enim Formation ranging from 31% in STC to 24% in S7 and is equal to 16% in S8-S13. Initial water saturation was derived by client as 35% in STC-S7 and 40-45% in S8-S13 which are considered reasonable. Due to shortage of time, Austar Gas has used the information from the top structure

and the net pay maps provided by PKM but it has adjusted the net pay in S1-S7 using the correction factors suggested in the previous independent reserves review report from 2015.

KM field is a mature field with \~330 wells drilled at dense spacing (10 to 30 acres depends on the zone/block) with cumulative production over 12 million barrels (\~18.5% of OOIP). However, lack of consistent reservoir management during the water injection trials and issues regarding artificial

lifting in some of the blocks has lowered the production performance at KM. Since 2011, PKM has brought online nine new wells and carried out over 30 workovers (mainly re-perforation or pump replacement in existing producers) that in most cases resulted in production gains. As of 31 December 2016, there were 30 existing oil producers in KM field.

The proposed development plan for KM field by Austar Gas is based on the information provided by PKM and the cost assumptions provided in the previous reserves estimate in 2015. The proposed development plan includes workover of existing wells and drilling new producing and water injection wells at KM filed. Austar Gas suggests that PKM should also consider other technologies such as radial drilling/ jetting, hydraulic fracturing, liquid Nitrogen injection and propellant stimulation trials to unlock the potential from Muara Enim and the Air Benakat Formations.

Well costs including completion and connection to surface facilities are approximately US\$400,000/- for new wells and US\$80,000/- for recompletion of existing wells. For the base case (2C) the proposed program requires drilling of 4 new producers and recompletion of 30 existing producers. For 1C the program requires drilling of 3 new wells, 31 recompletions of existing wells and 2 injectors and for 3C it requires drilling of 12 wells, recompletion of 75 existing wells and 40 water injection wells. As of 31 December 2016, there were 30 wells producing with oil production. Figure 1 shows a summary of field deliverability outputs which was resulted for KM field oil production forecast from 2017 to 2035.

Figure 1. KM oilfield deliverability forecast for 1C, 2C & 3C production outlook