Sound Energy on Jan. 7 provided an update on the company’s TE-10 exploration well following the identification of gas bearing sands within and below the currently mapped TAGI structural closure, which potentially materially de-risks the stratigraphic upside in North East Lakbir in the company’s Greater Tendrara license area.

The North East Lakbir stratigraphic trap had a pre-drill mid case potential on a gross (100%) basis of 2.7 trillion cubic feet (Tcf) gas originally in place (GOIP) (4.5 Tcf GOIP upside case and a 1.5 Tcf GOIP low case) and the smaller TAGI structural closure had a mid-case potential, on a gross (100%) basis, of 128 billion cubic feet (Bcf) GOIP (210 Bcf GOIP upside case and a 75 Bcf low GOIP case).

The company also confirms the achievement of total depth (TD) with TE-10, the potential identification of additional thin bedded net pay and the successful recovering of a gas sample to surface.

The TE-10 well was the second in Sound Energy’s current three well exploration program in the Tendrara area designed to explore three geologically-independent plays and to establish the potential of the basin. The well is located approximately 25 km (15 miles) to the northeast of the recently awarded Tendrara production concession, which contains the TE-5 Horst discovery unlocked by Sound Energy in 2016-2017.

The TE-10 well has been drilled to a TD at 2,218 m (7,276 ft) measured depth (MD), 209 m (685 ft) MD below the base of the TAGI sandstone sequence, in an, as yet, undated section of mudstones and minor thin bedded sandstones, with gas shows down to 2,070 m (6,791 ft) MD.

The company announced the preliminary results of the intermediate TE-10 logging results in December 2018, which included a potential TAGI gross reservoir sequence from 1,899 m (6,230 ft) MD to 2,009 m (6,591 ft) MD and an initial net pay estimate of up to 10.5 m (34.4 ft), with an average porosity of 8%.

The company has now completed the FMI (high definition formation micro-imager log) which provides a microresistivity image of the well bore at a much finer resolution than the initial logging suite. Significantly, the FMI has potentially identified the presence of additional thin bedded net pay within the previously identified potential gross reservoir interval between 1,899 m (6,230 ft) MD to 2,009 m (6,591 ft) MD. Quantification of the overall net pay is underway and will require substantiation from side-wall core analysis and further wireline log evaluation.

The company is also very pleased to confirm that a gas sample (comprising C1 to C5 hydrocarbons) was successfully recovered from one of these pay intervals at approximately 1,937 m (6,354 ft) MD using a modular formation dynamics tester system (MDT). The successful retrieval of this gas sample confirms the presence of moveable hydrocarbons in the reservoir, and importantly is the first successful MDT gas test from the TAGI sandstone in the Tendrara license (where testing has historically been hampered by the tight nature of the sandstone).

Following the acquisition of the vertical seismic profile, the company can confirm that the gas shows observed extend below the currently mapped structural closure at approximately 1,958 m 6,423 ft) MD. This suggests the gas accumulation may extend updip into the stratigraphic trap. Seismic interpretation and modelling is underway to assist with internal estimates of gas resources within the discovery.

With drilling operations now concluded, plans are now in progress to conduct a well test over the reservoir interval. This is expected to occur during February 2019, after rig de-mobilization and mobilization of the necessary testing equipment.

Offshore