Reserves and Resources
As at June 30, 2021 Cue has reported 4.4 mmboe of proven (1P) reserves and 6.0 mmboe of Proven and Probable (2P) reserves. 80% of reported 2P reserves are gas and 20% are oil.
RESERVES COMPLIANCE STATEMENTS
Oil and gas reserves, and contingent and prospective resources, are reported as at 1 July 2021 and follow the SPE PRMS Guidelines (2018). The volumes presented are net to Cue Energy. Cue currently holds an equity position of 5%, 15% and 12.5% in the Maari, Sampang and Mahato assets respectively, though Production Sharing Contract adjustments at the Sampang & Mahato fields affect the net equity differently across the various reserve categories. In the Amadeus basin, all fields and prospects are non-operated, with the operator being Central Petroleum Limited. Cue holds 7.5% equity in Mereenie and 15% in Palm Valley and Dingo.
Mereenie, Palm Valley and Dingo reserves are based on historical field production data and various well intervention and drilling campaigns. This data has been combined with available seismic data, analytical and numerical analysis methods and a set of deterministic reservoir simulation and network models. In-place volumes have been developed using probabilistic methods, with deterministic workflows used for recoverable volumes. The reserves and resource volumes stated have not been adjusted for risk. In New Zealand, the Maari field is non-operated. The operator is OMV. In Indonesia, all fields and prospects are non-operated, the operator at Sampang is Medco and at Mahato is Texcal. For Sampang, a combination of deterministic and analytical methods have been applied in tandem with a review of the available simulation models, by NZOG in determining remaining reserves.
At all fields, economic modelling has been conducted to determine the economically recoverable quantities. For the conversion to equivalent units, standard industry factors have been used of 6Bcf to 1mmboe, 1Bcf to 1.05PJ, 1 tonne of LPG to 8.15 boe and 1TJ of gas to 163.4 boe. Proven (1P) reserves are estimated quantities of oil and gas which geological and engineering data demonstrate with reasonable certainty (90% chance) to be recoverable in future years from known reservoirs, under existing economic and operating conditions. Probable (2P) reserves have a 50% chance or better of being technically and economically producible using discounted cashflows. The oil price assumptions are based on a futures price curve, followed by a flat real price. For gas volumes in excess of current contracts, a future base market price from an independent expert report is assumed for gas sales.
Known accumulations are reserves or contingent resources that have been discovered by drilling a well and testing, sampling or logging a significant quantity of recoverable hydrocarbons. Developed reserves are expected to be recoverable from existing wells and facilities. Undeveloped reserves will be recovered through future investments (e.g. through installation of compression, new wells into different but known reservoirs, or infill wells that will increase recovery). Total reserves are the sum of developed and undeveloped reserves at a given level of certainty.
All reserves and resources reported refer to hydrocarbon volumes postprocessing, net of fuel, and immediately prior to point of sale. The volumes refer to standard conditions, defined as 14.7psia and 60°F. The extraction method is via the Mereenie and Palm Valley Gas Plants which includes compression and dehydration. Tables combining reserves have been calculated arithmetically and some differences may be present due to rounding.
This reserves and resources statement for all fields except Mahato(see below) is approved by, based on, and fairly represents information and supporting documentation prepared by New Zealand Oil & Gas Assets & Engineering Manager Daniel Leeman. Daniel is a Chartered Engineer with Engineering New Zealand and holds Master’s degrees in Petroleum and Mechanical Engineering as well as a Diploma in Business Management and has over 10 years of experience. Daniel is also an active professional member of the Society of Petroleum Engineers and the Royal Society of New Zealand. New Zealand Oil & Gas reviews reserves holdings twice a year by reviewing data supplied from the field operator and comparing assessments with this and other information supplied at scheduled meetings. Daniel is currently an employee of New Zealand Oil & Gas Limited whom, at the time of this report, are a related party to Cue Energy. Daniel has been retained under a services contract by Cue Energy Resources Ltd (Cue) to prepare an independent report on the current status of the entity’s reserves. As of the 17th of January 2017, NZOG held an equity of 50.04% of Cue.
COMPLIANCE STATEMENT, MAHATO
The reserves stated for Mahato are effective 1 July 2021 and follow the SPE PRMS Guidelines (2018). Net reserves are presented net of equity, determined by economic modelling on discounted cash flows performed at the gross field level as approved under the standard SKK Migas Plan of Development process and exclude the Government of Indonesia estimated share of reserves under the Production Sharing Contract.
All reserves and resources reported refer to hydrocarbon volumes postprocessing, net of fuel, and immediately prior to point of sale. The volumes refer to standard conditions, defined as 14.7psia and 60°F. The extraction method is via EPF facilities which includes anThe extraction method is via EPF facilities which includes an oil and water separation system, with the oil then piped 6km to the CPI operated Petapahan Gathering Station.
This resources statement is based on, and fairly represents information and supporting documentation prepared by PT Gada Energi, a company owned by the Institut Teknologi Bandung (ITB) as the relevant certifying authority in accordance with the SPE PRMS Guidelines (2018).