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Guidelines for the Petroleum and Geothermal Energy Resource (Resource Management and Administration) Regulations 2014 • interpreted seismic data at a legible scale and format to be discussed with the Department; • formation parameters, including detailed log interpretation and core analysis (including information on normal and special core analysis work, drill stem tests (DST) and production testing); and • reservoir simulations may be presented in various ways, and discussion with the Department on the most appropriate form should be covered during the preparation of the preliminary field development plan. The following specifics should also be discussed, where appropriate: • projected annual production and injection rates, broken down into contributions from each production layer or zone, of: i. gas (methane plus ethane) content of produced fluids, with estimated specific gravities and provided at standard conditions (15 degrees Celcius, 101.325 kPa); ii. LPG (propane plus butane) content of produced fluids, with estimated specific gravities and provided at standard conditions (15 degrees Celcius, 101.325 kPa); iii. condensate (C5+); iv. crude oil; and v. water. • the extent to which these production profiles are dependent upon assumptions of well capacity, drilling sequence or other factors, and the range of uncertainty of these factors; • production process flow diagrams for each major system and a simplified mass balance for all oil, gas and gas liquids produced, utilised or transported for sale, including the use and disposal of separator gas; • a brief summary of methods for metering hydrocarbons produced and utilised, a description of systems for collecting and treating oil, water and other discharges, and a brief description of any fluid treatment and injection facilities; • the plateau or maximum hydrocarbon production rate (where appropriate), with supporting reasons for the level proposed, with particular attention to terminal rates of hydrocarbon and water production and demonstrated means of achieving separation of oil and water towards the end of the field’s economic life; • the proposed drilling pattern and program for wells, indicating the degree of flexibility and contingency built into the overall plan to allow the program to be altered in order to maximise on a commercial basis estimated hydrocarbon recovery, taking into account improved knowledge of the reservoir properties and performance as the field is developed; • the program for completion intervals and an indication of the completion and perforation philosophy; • any techniques for increasing or maintaining well productivity such as artificial gas lift or downhole pumps; • adequate description of other development options including subsurface and surface aspects, costings and (where relevant) the reasons for the rejection of the option; and • description of how the approved applicant intends to extract the petroleum over time, including the following information: i. the estimated positions of wells; ii. the potential timing of workover operations; and iii. possible tie-ins. In addition a FDP description of: • the essential elements of the planned management of the field, including subsurface safety considerations; and • management plans for reservoir depletion, including downhole pressure surveys, production logging, thermal decay time logging or other cased hole logs to indicate hydrocarbon contact positions. 5. SUBMISSION AND RELEASE OF PETROLEUM AND GEOTHERMAL ENERGY DATA Part 8, Data Management, of the (RMA) Regulations details the format, contents and standards required in the submission and preparation of petroleum exploration data. Petroleum data shall contain information of sufficient standard and detail to substantiate, to the satisfaction of the Minister, the expenditure claimed and the activities undertaken on a petroleum permit, lease, license, drilling reservations or special prospecting authority as reported to the Department. Part 9 of the (RMA) Regulations sets out the conditions under which technical information about petroleum could be released. These guidelines provide additional information to Part 8, 9 and Schedules of the regulations to assist industry in managing petroleum report, data and petroleum mining sample submission for geoscientific activities. These guidelines will be modified as required in accordance with prevailing petroleum legislation and supporting regulations and changes in technology. 5.1 DISTRIBUTION OF DATA Under Part 8 of the (RMA) Regulations, data shall be submitted to the Department of Mines and Petroleum for the following types of petroleum titles: • Exploration Permit (EP) • Drilling Reservation (DR) • Retention Lease (R) • Production License (L) • Special Prospecting Authority (SPA) • Scientific Investigation (SI) • Access Authority (AA) www.dmp.wa.gov.au | 12PDF Image | Western Australia Guidelines for Geothermal Energy Resource
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