works approval prescribed premises categories 12 and 52 ... · illustrates the south waste rock...

VERSION 2 19 FEBRUARY 2020

Works Approval

Prescribed Premises Categories 12 and 52 Crushing and Screening of Material and

Power Generation

SAVANNAH PROJECT

PREPARED BY:

Works Approval | Prescribed Premises Categories 12 & 52

2020 02 19_WA Support Document Att 3A_Final V2 i

Table of Contents 1. SUMMARY ............................................................................................................................................ 1

2. INTRODUCTION ..................................................................................................................................... 2

2.1 OWNERSHIP ......................................................................................................................................... 2 2.2 LOCATION, TENURE AND SITE LAYOUT .................................................................................................. 2 2.3 PROPOSED PRESCRIBED PREMISE CATEGORIES ................................................................................... 2

3. EXISTING ENVIRONMENT ...................................................................................................................... 3

3.1 REGIONAL SETTING .............................................................................................................................. 3 3.2 CLIMATE .............................................................................................................................................. 3 3.3 GEOLOGY AND WASTE ROCK CHARACTERISATION................................................................................. 3 3.4 SOILS .................................................................................................................................................. 4 3.5 HYDROLOGY ........................................................................................................................................ 4 3.5.1 Surface Water ..................................................................................................................................... 4 3.5.2 Groundwater ....................................................................................................................................... 4 3.6 FLORA AND VEGETATION ...................................................................................................................... 4 3.7 FAUNA AND HABITAT............................................................................................................................. 5 3.8 SOCIAL SETTING .................................................................................................................................. 6 3.8.1 Land Use and Community .................................................................................................................. 6 3.8.2 Aboriginal Heritage ............................................................................................................................. 6

4. PROJECT DESCRIPTION ........................................................................................................................ 7

4.1 CRUSHING AND SCREENING OF WASTE ROCK ....................................................................................... 7 4.2 POWER STATION AND EXPANSION OF POWER GENERATION INFRASTRUCTURE ....................................... 9

5. COMPLIANCE AND CONSULTATION ...................................................................................................... 13

5.1 COMPLIANCE ...................................................................................................................................... 13 5.2 CONSULTATION .................................................................................................................................. 13

6. CONTROL OF EMISSIONS .................................................................................................................... 14

6.1 RISK ASSESSMENT OVERVIEW ............................................................................................................ 14 6.2 RISKS AND IMPACT ASSESSMENT ........................................................................................................ 14 6.2.1 Emissions to Air ................................................................................................................................ 15 6.2.2 Noise Emissions ............................................................................................................................... 17 6.2.3 Discharge to Land and Water ........................................................................................................... 18

7. REFERENCES ..................................................................................................................................... 20

Tables Table 1: Summary of Commitments .......................................................................................................... 1

Table 2: Existing and Proposed Power Generation Infrastructure ........................................................... 10

Table 3: Risk Matrix ................................................................................................................................. 14

Table 4: Air Emission Sources, Receptors and Control Measures .......................................................... 15

Table 5: Noise Emission Sources, Receptors and Control Measures ..................................................... 17

Table 6: Emissions to Land and Water Sources, Receptors and Control Measures ............................... 18


2020 02 19_WA Support Document Att 3A_Final V2 ii

Figures Figure 1: Location Plan ............................................................................................................................... 1

Figure 2: Site Layout ................................................................................................................................... 1

Figure 3: Internal Roads to be Bituminised ................................................................................................. 8

Figure 4: Example of a Mobile Crushing and Screening Plant ................................................................... 9

Figure 5: Power Station and Additional Power Generation Infrastructure ................................................. 11

Figure 6: Proposed Expansion of Power Generation Infrastructure (Vent Fan/Chiller Area) .................... 12

Appendices Appendix 1: Engine Specification and Exhaust Emission Data Sheets ......................................................... 21

Appendix 2: Commissioning Plan .................................................................................................................. 22


2020 02 19_WA Support Document Att 3A_Final V2 1

1. SUMMARY This Works Approval has been prepared for the Savannah Nickel Project (Savannah, the Project) located in the East Kimberley Region of Western Australia, approximately 120 km north-northeast of Halls Creek. The Project is operated by Savannah Nickel Mines Pty Ltd (SNM), a wholly owned subsidiary of Panoramic Resources Limited (Panoramic). Operations commenced in 2004 and comprise of an underground mine, paste plant, processing plant with tailings and water storage facilities, a decommissioned pit, supporting mine site infrastructure and an accommodation village. This Works Approval is made for the following Prescribed Premises categories:

• Category 12: Screening, etc. of material: premises (other than premises within category 5 or 8) on which material extracted from the ground is screened, washed, crushed, ground, milled, sized or separated (50,000 tonnes or more per year). It is proposed waste rock will be processed through a mobile crushing and screening plant to be situated on the upper surface of the South Waste Rock Dump (SWRD). Up to 500,000 tonnes (~300,000 m3) per annum of crushed waste rock will be used by WBHO Infrastructure Pty Ltd (WBHO) and Main Roads Western Australia (MRWA) for site maintenance purposes which triggers Category 12.

• Category 52: Electric power generation: premises (other than premises within category 53 or an emergency or standby power generating plant) on which electrical power is generated using a fuel (10 megawatts or more in aggregate (using a fuel other than natural gas)). Additional power generation infrastructure is required to meet current and future power generation requirements of the Project and ensure a safe working environment for underground personnel. This includes expansion of auxiliary power generators at the primary vent fan (located adjacent to the pit) and an increase in power generation from the existing power station (located adjacent to the processing plant and fuel farm). The total power generation from these facilities will total 25 MW (maximum capacity).

The existing power station and auxiliary power infrastructure has not previously triggered the threshold for Prescribed Premises. Following consultation with DWER it was communicated that the culmination of additional auxiliary infrastructure has resulted in the potential for power generation to exceed the Category 52 threshold, which requires a works approval and licence (pers. comm, Alana Kidd, 10 January 2020). This Works Approval seeks to retrospectively authorise power infrastructure that is required for ongoing operations. This supporting document describes the receiving environment and provides details on management of emissions and pollution control. Assessment of risks associated with the Project demonstrates that potential emissions and discharges can be effectively managed to ensure there are no significant impacts to ecological and human receptors. Relevant stakeholders have been engaged and consulted regarding this Works Approval including a meeting with Alana Kidd and Suzy Roworth from Department of Water and Environmental Regulation (DWER) on 25 September 2019, an email with Suzy Roworth on 4 November 2019 and an email with Alana Kidd on 10 January 2020. A summary of commitments made in this Works Approval is provided in Table 1.



Table 1: Summary of Commitments

Aspect Commitment No.

Commitment

Air Commitment 1 Generators and diesel engines will be maintained and serviced on a regular basis and according to the manufacturer’s specifications to ensure efficient running, optimum fuel consumption and minimised emissions.

Commitment 2 Low sulfur diesel will be used in equipment and generators. Commitment 3 Emissions from mining and associated activities will be detailed in the National

Pollutant Inventory (NPI) Report and National Greenhouse and Energy Report (NGER) submitted annually.

Commitment 4 Construction and commissioning activities will not be undertaken during periods of strong wind.

Commitment 5 Surface mobile equipment and light and heavy vehicles will keep to designated roads. Commitment 6 Vehicle speed limits will be applied to reduce dust generation from vehicle

movements. Commitment 7 The generation of fugitive dust emissions will be minimised using a combination of

water sprays, misters and water carts. Commitment 8 Regular inspections will be undertaken to evaluate the effectiveness of point source

dust control measures. Corrective action will be implemented where necessary. Commitment 9 Crushing and screening activities will not be undertaken during periods of strong wind. Commitment 10 Occupational hygiene requirements will be complied with in operational areas. Commitment 11 Vehicles and power generation equipment will be maintained to minimise emissions. Commitment 12 Dust suppression measures will be implemented as necessary during construction.

Noise Commitment 13 Compliance with the Environmental Protection (Noise) Regulations 1997. Commitment 14 All vehicles and plant equipment will be regularly maintained to ensure they are

operating efficiently and are not unduly noisy. Commitment 15 Where possible, mufflers and other noise attenuating equipment will be installed and

maintained on plant, vehicles and equipment so as to reduce exposure to occupational noise.

Commitment 16 Standard PPE will used by employees where required to reduce exposure to occupational noise.

Land and Water

Commitment 17 Surface mobile equipment, heavy and light vehicles will carry spill kits and be inspected and maintained on a regular basis.

Commitment 18 Heavy and light vehicle maintenance will be undertaken in designated workshop areas located on concrete pads constructed so that they drain to a clean water recovery system. Where maintenance activities occur outside of these areas, hydrocarbon spillages and leakages will be captured and appropriately managed through the use of drip trays and hydrocarbon absorbent materials.

Commitment 19 Soil contaminated by hydrocarbons will be treated in-situ, at the bioremediation pad or transported offsite to a controlled waste licenced facility for treatment.

Commitment 20 Storage of hydrocarbons will be undertaken in accordance with existing approvals.



2. INTRODUCTION

2.1 Ownership The Savannah Nickel Project is operated by Savannah Nickel Mines Pty Ltd (SNM), a wholly owned subsidiary of Panoramic Resources Limited (Panoramic). All compliance and regulatory requirements regarding this assessment document should be forwarded by email or post to the following address: Contact: Ms Tahlia Walsh, Environment and Heritage Superintendent Postal address: PO Box Z5487, Perth, WA, 6831 Telephone: 0466 425 665 Email: [email protected]

2.2 Location, Tenure and Site Layout The Project is located approximately 40 km south of Warmun and 120 km north of Halls Creek in the East Kimberley region of Western Australia and is accessed via the Great Northern Highway (Figure 1). The Project is located on Mining Leases M80/179, M80/180, M80/181 and Miscellaneous Lease L80/64. Figure 2 illustrates the South Waste Rock Dump (SWRD) where the mobile crushing and screening plant will be located, in addition to the location of the existing power station and auxiliary power generation infrastructure.

mailto:[email protected]



2.3 Proposed Prescribed Premise Categories The Project is currently licenced under L7967/2003/6 for the following Prescribed Premises:

• Category 5: Processing or beneficiation of metallic or non-metallic ore: premises on which - 50 000 tonnes or more per year (a) metallic or non-metallic ore is crushed, ground, milled or otherwise processed; (b) tailings from metallic or non-metallic ore are reprocessed; or (c) tailings or residue from metallic or non-metallic ore are discharged into a containment cell or dam. (processing or beneficiation of metallic or non-metallic ore).

• Category 54: Sewage facility: premises (a) on which sewage is treated (excluding septic tanks); or (b) from which treated sewage is discharged onto land or into waters (100 cubic metres or more per day).

• Category 64: Class II putrescible landfill site: premises on which waste (as determined by reference to the waste type set out in the document entitled “Landfill Waste Classification and Waste Definitions 1996” published by the Chief Executive Officer and as amended from time to time) is accepted for burial (20 tonnes or more per annum).

The proposed Prescribed Premises categories applicable to this Works Approval include:

• Category 12: Screening, etc. of material: premises (other than premises within category 5 or 8) on which material extracted from the ground is screened, washed, crushed, ground, milled, sized or separated (50,000 tonnes or more per year).

• Category 52: Electric power generation: premises (other than premises within category 53 or an emergency or standby power generating plant) on which electrical power is generated using a fuel (10 megawatts or more in aggregate (using a fuel other than natural gas)).



3. EXISTING ENVIRONMENT

3.1 Regional Setting The Savannah Project is located in the east Kimberley region of Western Australia. The closest population centre is the township of Warmun, located approximately 40 km northeast of the Project. The region is sparsely populated. The main economic activities occurring in the vicinity of the Savannah Project are pastoral activities and tourism.

3.2 Climate The climate of the Savannah area is sub-tropical and is characterised by humid summers and dry winters. The wet season associated with summer brings frequent storms associated with the formation of the monsoonal depression over the northern Australian tropics. Severe weather associated with tropical cyclones or rain bearing depressions (ex-tropical cyclones) occasionally bring intense rainfall and lead to flooding. Most of the rainfall occurs in the wet season and is associated with stream flow events across the Project area. Daily rainfall data has been collected at Savannah (local readings) since November 2003. This data is comparable with rainfall and evaporation data from the closest Bureau of Meteorology (BOM) Stations located at Warmun (approximately 40 kilometres to the northeast) and Halls Creek Airport (approximately 110 km to the southwest). Meteorological data for Warmun and Halls Creek is presented in Chart 1.

Chart 1 : Meteorologica l Data for Warmun and Hal ls Creek

3.3 Geology and Waste Rock Characterisation The Project is located within a sequence of early Proterozoic rocks referred to as the Halls Creek Mobile Zone (HCMZ). The HCMZ can be divided into three tectono-stratigraphic zones; the Eastern, Central and Western zones, which are bounded by northeast trending strike slip faults. The Savannah Project is located in the Central Zone which is bounded by the Halls Creek, Angelo and Osmond Faults to the east, and the Ramsay Range and Springvale Faults to the west. The Tickalara Metamorphics, a deformed sequence of interbedded mafic metavolcanics and metasediments, are the oldest and most dominant rock type of the Central Zone. Numerous felsic and layered mafic to ultramafic complexes intrude the metamorphics, including the Sally Malay layered complex. Previous geochemical studies undertaken by Graeme Campbell and Associates (2002), MBS Environmental (2008) and RGS (2009 and 2016) have consistently demonstrated that the waste lithologies at Savannah, in particular the gneissic bedrock lithologies, Tickalara Metamorphics (TM) and Turkey Creek Gabbro (TCG), are predominantly Non-Acid Forming (NAF).



3.4 Soils Topsoils and subsoils within the Project area comprise medium density (stiff to hard), brown to red brown, slightly moist to dry, low to intermediate plasticity, fine grained sandy silts, generally extending to depths of 0.2 to 0.8 m overlying weathered rock. Geochemical analyses indicate that the soils have a neutral pH, a low concentration of soluble salts, no sulphide minerals with a low capacity to consume acid and a low concentration of environmentally significant metals. The results of analyses of plant nutrient characteristics indicate:

• The soils are typical of sub-tropical soils in Western Australia, with low organic matter and available phosphorus contents.

• Phosphorus and nitrogen are likely to be the limiting nutrients however local plants are adapted to low nutrient levels and it is therefore unlikely that fertiliser will be required on rehabilitated areas.

3.5 Hydrology

3.5.1 Surface Water The Project is located within the Fletcher Creek catchment, part of the Ord River System, which also includes minor ephemeral creeks such as Stoney Creek and small drainage lines such as Mine Creek. Fletcher Creek catchment is divided into two sub-catchments, upstream and downstream of the confluence of Mine Creek. On the north and western sides of the Project is a catchment drained by Stoney Creek and on the eastern side is a catchment drained by Fletcher Creek. The central area of the Project drains to Mine Creek which drains eastwards to Fletcher Creek. The SWRD and primary vent fan/chiller areas are located high in the landscape on a ridgeline and situated over 30 m above the nearest watercourses in the respective valley floor (i.e. - Mine Creek and Rademy Creek) and will not be affected by flooding.

3.5.2 Groundwater Groundwater in the Project area primarily occurs in shallow weathered fractured rock, which responds rapidly to intensive rainfall and discharges to a network of surface drainages. Groundwater levels are closely related to the topographic elevations. Hydraulic conductivity of the thin layer of saturated weathered bedrock is generally low in the topographic high area and relatively high in thicker sequences in the topographic low area near Fletcher Creek. Groundwater from rainfall recharge events collects in aquifers along the valley floors after the wet season and flows down gradient to discharge either to the surface in local creeks (as springs) or superficial aquifers either in the alluvium or uppermost fractured rock interval where it is consumed by evapotranspiration.

3.6 Flora and Vegetation The most recent flora and vegetation assessment at the Project was completed by Outback Ecology in 2011. The survey collected data from a total of 38 quadrats and 28 relevés within the Project area. A total 100 taxa from 32 families and 72 genera have been recorded with the most dominant genera being Acacia (5 taxa), Tephrosia (5 taxa) and Eucalyptus (5 taxa). One Priority flora taxon, Sorghum plumosum var. teretifolium (P1) was recorded and is noted to occur extensively across the wider Project area, associated with ephemeral, sandy and stoney based drainage lines and on the slopes above these drainage lines on skeletal sandy soils (Outback Ecology 2011). No threatened flora listed under Biodiversity Conservation Act 2016 (BC Act 2016) or under the Commonwealth Environment Protection and Biodiversity Conservation Act 1999 (EPBC Act 1999) were recorded and based on the survey undertaken and the habitat preferences of these species known to occur in the region, none are expected to occur in the Savannah Project area (Outback Ecology 2011).



Six introduced species, Aerva javanica, Portulaca oleracea, Vachellia farnesiana, Stylosanthes hamata, Malvastrum americanum and Calotropis procera were recorded within the Savannah Project area. Of these species, four are considered ‘Environmental Weeds’ by the Environmental Weed Strategy for Western Australia (DEC 1999). *Aerva javanica and *Calotropis procera are rated ‘high’, *Malvastrum americanum is rated moderate and *Stylosanthes hamata is rated ‘mild’. None of the introduced species are considered ‘Declared’ plants within the Halls Creek area.

3.7 Fauna and Habitat As part of pre-mining baseline studies, a reconnaissance and detailed fauna survey of the Project area was undertaken by Outback Ecology in October 2001 and August 2002 respectively. Updated searches of State and Federal databases were undertaken in 2011. The detailed survey recorded two amphibians (frogs) from one species, 22 reptiles from nine species,11 mammals from three species and 384 birds from 41 species. The results from the trapping program suggested that the Project area does not support an amphibian, reptile or mammal assemblage that differs in composition from that of the greater region. Three species protected under Federal and State legislation, have been recorded in the Project area. These are the Gouldian Finch (Erythrura gouldiae), Rainbow Bee-eater (Merops ornatus) and the Great Egret (Ardea alba).

Rainbow Bee-eater (Merops ornatus) The Rainbow Bee-eater was recorded in the 2002 survey. The Rainbow Bee-eater is a widespread migratory species that breeds in tunnels dug into sandy banks. The species is evaluated as ‘Least Concern’ by the International Union for Conservation of Nature (IUCN) with an extremely large population size that appears stable. The Rainbow Bee-eater has a diverse and widespread habitat preference that is well distributed in the region.

Great Egret (Ardea alba) The Great Egret was recorded during the 2002 survey at a site along Fletcher Creek. The Great Egret is a migratory species that inhabits tidal mudflats and margins or shallows of watercourses, inland swamps or dams. It is evaluated as Least Concern by the IUCN and is described as having an extremely large range and very large population size, although population trends are unknown. The Riverine land unit within the Project area provides potentially suitable habitat for the Great Egret. This land unit is well distributed in the wider region.

Gouldian Finch Habi tat (Erythrura gouldiae) Fauna and habitat surveys did not record the Gouldian Finch within the Project area, however the species has been observed by personnel in the vicinity of the Project. This species occurs on database searches as potentially present within the general area, with the Uplands and Riverine land units of the Project area potentially providing suitable habitat for the Gouldian Finch. The Gouldian Finch is distributed across northern Australia and inhabits open forests and woodlands with a grassy understorey. These finches are often found near fresh water, particularly in the dry season. Breeding generally occurs in hilly or rocky areas with Snappy Gum (Eucalyptus brevifolia), with the birds building nests in the E. brevifolia hollows. Gouldian Finches sometimes nest in small colonies and breeding occurs in winter (April to July). The decline in grass seed resources due to pastoral activities and altered fire regimes are thought to be the most likely causes of the decline in this species.



3.8 Social Setting

3.8.1 Land Use and Community The nearest communities to the Project are the Frog Hollow and Warmun Aboriginal Communities, which are 10 km and 40 km north of the Project area respectively. Halls Creek is another local community that is located 120 km south of the Project. The Project is located on Mabel Downs Pastoral Lease, an active pastoral station which Panoramic has developed a strong relationship with the pastoral company. The Port of Wyndham is located 250 km to the north, with the Savannah Project concentrate stockpiled and exported from the port.

3.8.2 Aboriginal Heritage Detailed heritage clearance surveys of the project area were undertaken in early April and August 2002. As a result of the two heritage clearance programs, the only identified site of significance was located approximately one km west of the current exploration camp, well away from the Project activities and infrastructure. In November 2007, the Kimberley Nickel Co-existence Agreement was signed between Panoramic and the registered native title parties for the area, namely the Purnululu and Malarngowem People. The Agreement provides the mechanisms for Panoramic to undertake all activities associated with Savannah, whilst ensuring the ongoing and future cultural heritage protection within the Savannah area.



4. PROJECT DESCRIPTION There are two aspects to the proposed works:

• Crushing and screening of waste rock to support MRWA road maintenance and construction works on the Great Northern Highway and a number of internal roadways within the Savannah Project.

• Upgrades to the existing power generation infrastructure.

4.1 Crushing and Screening of Waste Rock Up to 500,000 tonnes (~300,000 m3) per annum of crushed waste rock from the SWRD will be used by WBHO and MRWA for on and offsite maintenance purposes. MRWA is completing road construction and other road works on the Great Northern Highway, which commenced in June 2019. Under Section 185 (1) of the Land Administration Act 1997, MRWA is authorised to occupy land on which the Project is located for the purpose of materials extraction and public works construction. A number of existing roads and tracks within the Savannah Project will also be progressively bituminised using crushed rock as road base, sourced from the SWRD. The internal roads to be bituminised are shown in Figure 3. Minor upgrades/repairs to the main access road may also be undertaken. Waste rock will be picked up by an excavator and loaded into the mobile crushing and screening plant. The rock will be processed through a three stage mobile Terex 1180 Jaw Crusher or Maxtrack 1300 Cone designed crushing and screening plant to produce various sized products (Figure 4). The design consists of:

• Primary jaw crusher.

• Scalping screen (Terex 883+Heavy Duty Screener).

• Secondary cone crusher.

• Tertiary cone crusher.

• Product screen.

• Telestack TC420 conveyor. The mobile crushing and screening plant will be situated on the upper surface of the SWRD and will move across the SWRD surface as needed. No further processing is required. The screened product will be stockpiled and loaded by a front-end loader into trucks as required. Oversized screened material will be placed in the SWRD in accordance with existing approvals. All crushing, screening and hauling activities will be undertaken during the dry season.



Figure 4: Example of a Mobile Crushing and Screening Plant

4.2 Power Station and Expansion of Power Generation Infrastructure

The existing power station is located adjacent to the processing plant and fuel farm and consists of diesel generators and associated control infrastructure (Table 2, Figure 5). The emission point for the oily water treatment separator at the power station is already regulated under Condition 2.3.1 of L7967/2003/6. Auxiliary electrical infrastructure is also located at the primary vent fan/chiller area adjacent to the open pit and is comprised of high voltage transformers, chillers, air coolers, cooling towers, switch rooms, powerlines, fans and an ancillary control system (Table 2, Figure 5). The additional power generation infrastructure comprises installation of diesel generators, double skinned fuel tanks, high and low voltage transformers, high voltage switches, bund leakage level switches and warning alarms, cable trays and fuel piping (Table 2, Figure 5 and Figure 6). The increased electrical capacity is needed to meet current and future power requirements of the mine and ensure a safe working environment for underground personnel. The combined output of the new infrastructure with the existing power plant will not exceed 25 MW capacity, which triggers Category 52. Emissions of NOx are anticipated to be approximately 172,000 kg/year. Engine specification and exhaust emissions data sheets are provided in Appendix 1.



Table 2: Exist ing and Proposed Power Generation Infrastructure

Area Infrastructure Existing Capacity <10 MW Power station located adjacent to processing plant and fuel farm

• <10 MW diesel generators. • Associated control infrastructure.

Primary vent fan/chiller area • 4 x high voltage transformers. • 2 x 0.69 MW fans and ancillary control system. • 5 x 270 KW chillers. • 7 x bulk air coolers. • 2 x cooling towers. • 2 x 415 volt switch rooms.

Proposed Capacity Up to 15 MW Existing power station located adjacent to processing plant and fuel farm

• 3.5 MW diesel generators (MTU Friedrichshafen engine model 12V4000G61).

Primary vent fan/chiller area • 8 x 1.2 MW diesel generators (Cummins diesel generator C1250 D2R PowerBox 20X and engine model KTA50G3).

• 3 x 68,000 L double skinned diesel fuel tanks (refuelling connections are over a bund and concrete pad to capture any spills).

• 3 x high voltage transformers. • 2 x additional high voltage switches. • 2 x low voltage transformers. • Associated cable trays and diesel fuel piping.

Total Capacity 25 MW (maximum)



Figure 6: Proposed Expansion of Power Generation Infrastructure (Vent Fan/Chil ler Area)



5. COMPLIANCE AND CONSULTATION

5.1 Compliance Crushing and Screening of Waste Rock This Works Approval seeks to apply for Category 12 under Part V of the Environmental Protection Act 1986. An amendment to the existing site licence L7967/2003/6, issued under Part V of the Environmental Protection Act 1986, will be applied for in early to mid 2020 after approval has been received for this Works Approval and the associated Construction Compliance Reports have been submitted. A Mining Proposal (MP 75688) titled ‘Development of Savannah North Decline and extension to south waste rock dump - Addendum to NOI 4099 - Savannah Project’ was submitted to DMIRS on 15 August 2018 and approved on 30 October 2018 allowing development of a decline between the existing Savannah underground and the proposed Savannah North Underground Mine, with mine waste from the decline development to be stockpiled on an extension of the South Waste Rock Dump. A Mining Proposal for crushing and screening activities titled ‘Provision of Crushed Waste Rock for Use in Road Construction and Site Maintenance - Addendum to NOI 4099 (Version 2- July 2019)’ was first submitted to DMIRS on 20 May 2019 and approved on 23 July 2019.

Power Stat ion and Expansion of Power Generation Infrastructure The existing power station and auxiliary power infrastructure has not previously triggered the threshold for Prescribed Premises. Following consultation with DWER it was communicated that the culmination of additional auxiliary infrastructure has resulted in the potential for power generation to exceed the Category 52 threshold, which requires a works approval and licence (pers. comm, Alana Kidd, 10 January 2020). This Works Approval seeks to retrospectively authorise power infrastructure that is required for ongoing operations. An amendment to the existing site licence L7967/2003/6, issued under Part V of the Environmental Protection Act 1986, will be applied for in early-mid 2020 after approval has been received for this Works Approval and the associated Construction Compliance Reports have been submitted. Approval for the existing power station and existing electrical infrastructure at the primary vent fan area was approved under ‘Mining Proposal 72411. Addendum to MP 28210 and NOI 4099, Ventilation Intake Installation, Revision 1 (March 2018)’ and ‘Notice of Intent (NOI) 4099 (2002)’. A Mining Proposal for the expansion of power generation infrastructure at the primary vent fan/chiller area titled ‘Mining Proposal Addendum for Expansion of Power Generation Infrastructure’ (dated 26 November 2019) was submitted to DMIRS in November 2019 and approved on 13 January 2020.

5.2 Consultation Relevant stakeholders have been engaged and consulted regarding this Works Approval and the above-mentioned approvals including:

• A meeting with Alana Kidd and Suzy Roworth from DWER on 25 September 2019.

• An email with Suzy Roworth on 4 November 2019.

• An email with Alana Kidd on 10 January 2020.

• A conversation with Matt Boardman from DMIRS on 1 November 2019.

• Consultation with WBHO, MRWA and the Purnululu and Malarngowem People.



6. CONTROL OF EMISSIONS

6.1 Risk Assessment Overview A risk assessment was completed in accordance with the DWER Guidance Statement: Environmental Risk Assessment Framework (February 2017). The risk assessment process identified the following:

• The sources of pollution and where available, quantification of emissions.

• The pathway which pollution follows from the source to the receptor.

• The environmental and health receptors.

• The potential Impacts on the receptors from this source of pollution.

• The project specific controls and mitigation measures which will be applied to the Project.

• The likelihood, consequence and overall risk rating associated with this factor.

• The requirement for monitoring. Likelihood and consequence categories were derived from the DWER Guidance Statement (DWER 2017). The associated risk matrix is presented in Table 3.

Table 3: Risk Matr ix

Key sensitive receptors within the vicinity of the Project include:

• Employees.

• Flora, fauna and vegetation. The nearest communities to the Project comprise Frog Hollow Aboriginal Community (10 km), Mabel Downs Homestead (25 km) and Warmun (40 km). These communities are considered too distant from the operations to be considered as receptors.

6.2 Risks and Impact Assessment Potential impacts, control measures and risk evaluation associated with the proposal is detailed in the following sub-sections.



6.2.1 Emissions to Air Sources, receptors and control measures for emissions to air are shown in Table 4.

Table 4: Air Emission Sources, Receptors and Control Measures

Source Possible Receptors Potential Impacts Control Measures Likelihood Consequence Risk Mobile Crushing and Screening Plant Emissions to air associated with crushing and screening activities are expected to predominately comprise of dust particles (Total Suspended Solids), as well as combustion products from associated mobile equipment (SOx and NOx). The sources of these emissions include: • Activities involved with the

handling and transport of materials, ore/rock crushing and screening.

• Emissions from the combustion of diesel by surface mobile equipment and light and heavy vehicles.

• Employees. • Flora, fauna and

vegetation. • The closest off-site

communities comprise Frog Hollow Aboriginal Community (10 km), Mabel Downs Homestead (25 km) and Warmun (40 km).

• Reduced air quality/health impacts through inhalation.

• Reduced amenity.

• Decline in vegetation health through dust smothering vegetation.

Combustion Emissions: • Generators and diesel engines

will be maintained and serviced on a regular basis and according to the manufacturer’s specifications to ensure efficient running, optimum fuel consumption and minimised emissions (Commitment 1).

• Low sulfur diesel will be used in equipment and generators (Commitment 2).

• Emissions from mining and associated activities will be detailed in the National Pollutant Inventory (NPI) Report and National Greenhouse and Energy Report (NGER) submitted annually (Commitment 3).

Dust Emissions: • Construction and commissioning

activities will not be undertaken during periods of strong wind (Commitment 4).

• Surface mobile equipment and light and heavy vehicles will keep to designated roads (Commitment 5).

• Vehicle speed limits will be applied to reduce dust generation

Possible Slight (minimal on-site impact to air).

Low



Source Possible Receptors Potential Impacts Control Measures Likelihood Consequence Risk from vehicle movements (Commitment 6).

• The generation of fugitive dust emissions will be minimised using a combination of water sprays, misters and water carts (Commitment 7).

• Regular inspections will be undertaken to evaluate the effectiveness of point source dust control measures. Corrective action will be implemented where necessary (Commitment 8).

• Crushing and screening activities will not be undertaken during periods of strong wind (Commitment 9).

• Occupational hygiene requirements will be complied with in operational areas (Commitment 10).

Expansion of Power Generation Infrastructure Power generation will produce greenhouse gas emissions including approximately 172,000 kg/year of NOx. Power generation will produce fugitive particulate emissions, notably PM10 and PM2.5. Fugitive dust emissions may be generated during construction and installation of power generation infrastructure.






• Vehicles and power generation equipment will be maintained to minimise emissions (Commitment 11).

• Dust suppression measures will be implemented as necessary during construction (Commitment 12).


Low

Given the remoteness of the Project, distance from the nearest potential receptors i.e. 10 km (Frog Hollow Aboriginal Community), dust and combustion emissions are expected to have a low impact upon human receptors. Employees of the Project will wear Personal Protective Equipment (PPE) as required and the controls discussed above will ensure that employees of the Project are not significantly impacted. The proposed control measures will also minimise potential impacts on flora and vegetation.



6.2.2 Noise Emissions Sources, receptors and control measures for noise emissions are shown in Table 5.

Table 5: Noise Emission Sources, Receptors and Control Measures

Source Possible Receptors Potential Impacts Control Measures Likelihood Consequence Risk Mobile Crushing and Screening Plant • Processing activities

(crushing, grinding, conveying).

• Construction and earthwork activities.

• Mobile and static equipment noise from engines.

• Road noise from surface mobile equipment and light and heavy vehicles.

• Generator noise.

• Employees. • Fauna. • The closest off-site communities

comprise Frog Hollow Aboriginal Community (10 km), Mabel Downs Homestead (25 km) and Warmun (40 km).

Reduced noise quality/health impacts through hearing loss and nuisance.

• Compliance with the Environmental Protection (Noise) Regulations 1997 (Commitment 13).

• All vehicles and plant equipment will be regularly maintained to ensure they are operating efficiently and are not unduly noisy. (Commitment 14).

• Where possible, mufflers and other noise attenuating equipment will be installed and maintained on plant, vehicles and equipment so as to reduce exposure to occupational noise (Commitment 15).

• Standard PPE will used by employees where required to reduce exposure to occupational noise (Commitment 16).

Possible Slight Low

Expansion of Power Generation Infrastructure • Construction and

earthwork activities. • Mobile and static

equipment noise from engines.





• As above. Possible Slight Low

Noise will be managed in accordance with Regulation 13 of the Environmental Protection (Noise) Regulations 1997. Given the remoteness of the Project and distance from receptors, noise levels are expected to have a low impact. Fauna will likely move away from the area during noisy periods. Employees will wear PPE as required.



6.2.3 Discharge to Land and Water Sources, receptors and control measures for discharge to land and water are shown in Table 6.

Table 6: Emissions to Land and Water Sources, Receptors and Control Measures

Source Possible Receptors Potential Impacts Control Measures Likelihood Consequence Risk Mobile Crushing and Screening Plant Spillage, leakage and seepage of hydrocarbon contaminants associated with accidents, breakdowns or malfunctions from surface mobile equipment, light and heavy vehicles.

• Employees. • Soil. • Flora, fauna and

vegetation. • Surface water. • The closest off-site


• Localised spillage, leakage and seepage of hydrocarbon contaminants to soil and surrounding drainage lines.

• Groundwater is unlikely to be affected considering the SWRD is located high in the landscape on a ridgeline and is situated over 30 m above the nearest watercourse in the valley floor (Mine Creek).

• Surface mobile equipment, heavy and light vehicles will carry spill kits and be inspected and maintained on a regular basis (Commitment 17).

• Heavy and light vehicle maintenance will be undertaken in designated workshop areas located on concrete pads constructed so that they drain to a clean water recovery system. Where maintenance activities occur outside of these areas, hydrocarbon spillages and leakages will be captured and appropriately managed through the use of drip trays and hydrocarbon absorbent materials (Commitment 18).

• Soil contaminated by hydrocarbons will be treated in-situ, at the bioremediation pad or transported offsite to a controlled waste licenced facility for treatment (Commitment 19).

• Storage of hydrocarbons will be undertaken in accordance with existing approvals (Commitment 20).

Possible Slight Low

Expansion of Power Generation Infrastructure Spillage, leakage and seepage of hydrocarbons associated with accidents, breakdowns or malfunctions from power generation equipment including generators, fuel

• Soil. • Surface water. • Flora, fauna and

vegetation. • Groundwater. • The closest off-site

communities comprise


• Existing areas have been heavily compacted

• Soil contaminated by hydrocarbons will be treated in-situ, at the bioremediation pad or transported offsite to a controlled waste licenced facility for treatment (As above).

• Storage of hydrocarbons will be undertaken in accordance with existing approvals (As above).

Possible Slight Low



Source Possible Receptors Potential Impacts Control Measures Likelihood Consequence Risk tanks, transformers and fuel piping.

Frog Hollow Aboriginal Community (10 km), Mabel Downs Homestead (25 km) and Warmun (40 km).

through extensive ongoing use over a period of years.

• Groundwater is unlikely to be affected considering the primary vent fan area is located high in the landscape adjacent to the open pit.

It is anticipated that potential impacts associated with hydrocarbon spills, groundwater and surface water contamination can be effectively managed through implementation of controls described above.



7. REFERENCES Bureau of Meteorology. Climate Statistics for Australian Locations: Warmun. http://www.bom.gov.au/climate/averages/tables/cw_002032.shtml. Accessed 20 November 2019.

Department of Water and Environmental Regulation (DWER) (2017). Guidance Statement: Risk Assessments Part V, Division 3, Environmental Protection Act 1986.

Graham Campbell and Associates Pty Ltd, 2002a. Sally Malay Project. Geochemical Characterisation of Mine Waste and Soil Samples (‘Static Tests’). Implications for Material Management. Included as part of Notice of Intent to Mine, Appendix 1 Volume 3, September 2002.

Graham Campbell and Associates Pty Ltd, 2002b. Sally Malay Project. Geochemical Characterisation of Process-Tailings and DMS-Rejects Samples (‘Static Tests’). Implications for Material Management. Included as part of Notice of Intent to Mine, Appendix 1 Volume 3, September 2002.

Graham Campbell and Associates Pty Ltd, 2002c. Sally Malay Project. Geochemical Testing of Process-Tailings, Mine-Waste, Strata and Groundwater Samples (‘kinetic-testwork’). Implications for Process-Tailings and Mine Waste Management. Included as part of Notice of Intent to Mine, Appendix 1 Volume 3, September 2002.

MBS Environmental, 2008. Waste Rock Characterisation Study. Unpublished report prepared for Savannah Nickel Mines Pty Ltd.

O;Kane Consultants. 2012. Savannah Nickel Mine Waste Rock Dump Landform Design Final Report. An unpublished report prepared for Panoramic Resources Ltd.

Outback Ecology Services. 2002. Sally Malay Mining Ltd –Baseline Environmental Studies. Included as part of Notice of Intent to Mine, September 2002.

Outback Ecology Services. 2011. Panoramic Resources Savannah Nickel. Level 1 Flora and Vegetation Assessment of the Tailings Storage Facility (TSF) Options. Report prepared for Panoramic Resources Limited.

RGS Environmental, 2009a. Geochemical Assessment of Tailings: Proposed Amendment to Tailings Storage Facility - Savannah Nickel Mines. Final report number R001A (780026) prepared by RGS Environmental Pty Ltd for Savannah Nickel Mines Pty Ltd, 21 April 2009.

RGS Environmental, 2009b. Completion of Kinetic Geochemical Assessment of Tailings Material – Savannah Nickel Project: Letter Report. Unpublished report prepared for Savannah Nickel Mines Pty Ltd, 11 August 2009.

RGS Environmental, 2009c. Geochemical Assessment of TSF Tailings at Depth, Savannah Nickel Project. Unpublished report prepared by RGS Environmental Pty Ltd for Savannah Nickel Mines, 15 October 2009.

Savannah Nickel Mines Pty Ltd, 2018. Mine Closure Plan, Savannah Project, M80/179, M80/180, M80/181 and L80/64 Version 4 (Document ID: SNMSMCP.

http://www.bom.gov.au/climate/averages/tables/cw_002032.shtml



APPENDIX 1: ENGINE SPECIFICATION AND EXHAUST EMISSION DATA SHEETS

MTU Friedrichshafen

Technical Sales Documentation MTU Project No. - ENGINE DATA -

Printout: (y-m-d) 2004-02-04 Sheet 1

No. Index Unit 12V4000G61

Application Group 3BMTU data code 1Intake air temperature °C 25Charge-air coolant temperature °C 55Barometric pressure mbar 1000Site altitude above sea level m 100Raw-water inlet temperature °C -

Explanation: A = Design Value N = Not yet defined valueG = Guaranteed value - = Not applicable

CP = Ref.value: Continuous power R = Guideline value X = ApplicableFSP = Ref.value: Fuel stop power L = Limit value, up to which the engine can be operated, Z = See notes provided after "ENGINE DATA"

without change (e.g. of power setting).

0. DATA-RELEVANT ENGINE DESIGN CONFIGURATION

1 Fuel-consumption optimized X

2 Exhaust-emissions optimized --(limit values see Exhaust Emissions, Chapter 21)

16 Complies with: TA-Luft (Edition 1986) --(German clean-air standard)

17 Complies with: --Regulations for stationary power plants in France(arrêté du 25 Juillet 1997)

18 Complies with: --US EPA, regulation for non-road mobile machinery(40 CFR 89 - stage I -)

33 Complies with: --US EPA regulations for non-road mobile machinery(40 CFR 89 - stage I -) NOx-40%

25 Complies with: --US EPA, regulation for non-road mobile machinery(40 CFR 89 - stage II -)

8 Engine rated speed switchable --(1500/1800 rpm)

12 Engine with sequential turbocharging --(turbochargers with cut-in/cut-out control)

13 Engine without sequential turbocharging X(turbochargers without cut-in/cut-out control)

1. POWER-RELATED DATA (power ratings are net brake power to ISO 3046)

1 Engine rated speed A 15001/min

3 Mean piston speed 9.5m/s

4 Continuous power ISO 3046 (10% overload capability) A 1330kW(design power DIN 6280, ISO 8528)

5 Fuel stop power ISO 3046 A 1463kW

8 Mean effective pressure (MEP) 21.8bar(Continuous power ISO 3046)

9 Mean effective pressure (MEP) 24.0bar(Fuel stop power ISO 3046)

51 Power take-off from aux. PTOs, L 40% von Ptotal max.(P = engine rated power)

2. GENERAL CONDITIONS (for maximum power)

1 Intake air depression (new filter) A 30mbar

2 Intake air depression, max. L 50mbar

3 Exhaust backpressure A 30mbar

4 Exhaust backpressure, max. L 51mbar

5 Fuel temperature at fuel feed connection R 25°C

3. CONSUMPTION

17 Specific fuel consumption (be) - 100% CP G 189g/kWh(+5%; EN 590; 42.8MJ/kg)

18 Specific fuel consumption (be) - 75% CP R 192g/kWh(+5%; EN 590; 42.8MJ/kg)


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21 Specific fuel consumption (be) - FSP R 189g/kWh(+5%; EN 590; 42.8MJ/kg)

73 No-load fuel consumption R 21.0kg/h

78 Lube oil consumption after run-in R 0.5% von B(B = fuel consumption per hour)

4. MODEL-RELATED DATA (basic design)

3 Engine with exhaust turbocharger (ETC) and intercooler X

4 Exhaust piping, non-cooled X

5 Exhaust piping, liquid-cooled --

33 Working method: four-cycle, diesel, single-acting X

34 Combustion method: direct injection X

36 Cooling system: conditioned water X

37 Direction of rotation: c.c.w. (facing driving end) X

6 Number of cylinders 12

7 Cylinder configuration: V angle 90degree

10 Bore 165mm

11 Stroke 190mm

12 Displacement, cylinder 4.06liter

13 Displacement, total 48.7liter

14 Compression ratio 15.5

40 Cylinder heads: single-cylinder X

41 Cylinder liners: wet, replaceable X

42 Piston design: composite piston X

49 Piston design: solid-skirt piston --

24 Number of inlet valves, per cylinder 2

25 Number of exhaust valves, per cylinder 2

15 Number of turbochargers 4

18 Number of intercoolers 1

28 Standard flywheel housing flange (engine main PTO) 00SAE

50 Static bending moment at standard L 15kNmflywheel housing flange, max.

51 Dynamic bending moment at standard L 75kNmflywheel housing flange, max.

43 Flywheel interface 21"DISC

46 Engine mass diagram, drawing No.

47 Engine mass diagram, drawing No. (cont.)

5. COMBUSTION AIR / EXHAUST GAS

8 Charge-air pressure before cylinder - CP R 3.0bar abs

27 Charge-air pressure before cylinder - FSP R 3.2bar abs

9 Combustion air volume flow - CP R 1.6m3/s

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10 Combustion air volume flow - FSP R 1.7m3/s

11 Exhaust volume flow (at exhaust temperature) - CP R 3.9m3/s

12 Exhaust volume flow (at exhaust temperature) - FSP R 4.2m3/s

15 Exhaust temperature after turbocharger - CP R 460°C

16 Exhaust temperature after turbocharger - FSP R 470°C

6. HEAT DISSIPATION

15 Heat dissipated by engine coolant - CP R 590kWwith oil heat, without charge-air heat

16 Heat dissipated by engine coolant - FSP R 650kWwith oil heat, without charge-air heat

26 Charge-air heat dissipation - CP R 250kW

27 Charge-air heat dissipation - FSP R 275kW

31 Heat dissipated by return fuel flow - CP R 14kW

32 Heat dissipated by return fuel flow - FSP R 14kW

33 Radiation and convection heat, engine - CP R 75kW

34 Radiation and convection heat, engine - FSP R 75kW

7. COOLANT SYSTEM (high-temperature circuit)

17 Coolant temperature A 95°C(at engine outlet to cooling equipment)

57 Coolant temperature differential after/before engine, from R 7°C

58 Coolant temperature differential after/before engine, to R 9°C

23 Coolant temperature differential after/before engine L °C

20 Coolant temperature after engine, alarm R 97°C

21 Coolant temperature after engine, shutdown L 99°C

25 Coolant antifreeze content, max. L 50%

30 Cooling equipment: coolant flow rate A 56m3/h

35 Coolant pump: inlet pressure, min. L 0.4bar

36 Coolant pump: inlet pressure, max. L 1.5bar

41 Pressure loss in off-engine cooling system, max. L 0.7bar

47 Breather valve (expansion tank) R 1.0baropening pressure (excess pressure)

48 Breather valve (expansion tank) R -0.1baropening pressure (depression)

54 Cooling equipment: height above engine, max. L 15.2m

53 Cooling equipment: operating pressure A 2.5bar

73 Coolant level in expansion tank, below min., alarm L --

74 Coolant level in expansion tank, below min., shutdown L X

50 Thermostat, starts to open R 79°C

8. COOLANT SYSTEM (low-temperature circuit)

9 Coolant temperature before intercooler A 55°C(at engine inlet from cooling equipment)

14 Coolant temperature before intercooler, alarm R 67°C

61 Coolant temperature before intercooler, shutdown L --°C

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54 Coolant temperature differential after/before L 11°Cintercooler, min.

55 Coolant temperature differential after/before L 13°Cintercooler, max.

13 Coolant antifreeze content, max. L 50%

17 Charge-air coolant temperature after intercooler, max. L 70°C

45 Charge-air coolant temperature after intercooler, max. L °Cfor compliance with TA-Luft (german clean airlegislation) at CP

20 Cooling equipment: coolant flow rate A 19m3/h

21 Intercooler: coolant flow rate R 19m3/h

24 Coolant pump: inlet pressure, min. L bar

25 Coolant pump: inlet pressure, max. L 1.5bar

29 Pressure loss in off-engine cooling system, max. L 0.7bar

43 Cooling equipment: height above engine, max. L 10m

36 Breather valve (expansion tank) R 1.0baropening pressure (excess pressure)

37 Breather valve (expansion tank) R -0.1baropening pressure (depression)

42 Cooling equipment: operating pressure A 2.5bar

67 Coolant level in expansion tank, below min., alarm L --

68 Coolant level in expansion tank, below min., shutdown L X

39 Thermostat, starts to open R 45°C

10. LUBE OIL SYSTEM

1 Lube oil operating temp. before engine, from R 85°C

2 Lube oil operating temp. before engine, to R 95°C

5 Lube oil temperature before engine, alarm R 95°C

6 Lube oil temperature before engine, shutdown L --°C

8 Lube oil operating press. bef. engine, from R 5.0bar

9 Lube oil operating press. bef. engine, to R 6.0bar

10 Lube oil pressure before engine, alarm R 4.5bar

11 Lube oil pressure before engine, shutdown L 4.0bar

19 Lube oil fine filter (main circuit): 4number of units

20 Lube oil fine filter (main circuit): 1number of elements per unit

21 Lube oil fine filter (main circuit): R 0.012mmparticle retention

32 Lube oil fine filter (main circuit): L 1.5barpressure differential, max.

11. FUEL SYSTEM

1 Fuel pressure at fuel feed connection, min. L -0.1bar(when engine is starting)

2 Fuel pressure at fuel feed connection, max. L 1.5bar(when engine is starting)

37 Fuel supply flow, max. R 18.0liter/min

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8 Fuel return flow, max. R 12.7liter/min

10 Fuel pressure at return connection on engine, max. L 0.5bar

12 Fuel temperature differential before/after engine R 35°C

38 Fuel temperature after high-pressure pump, Alarm L °C

39 Fuel temperature after high-pressure pump, Shutdown L °C

15 Fuel prefilter: number of units A

16 Fuel prefilter: number of elements per unit A

17 Fuel prefilter: particle retention A mm

18 Fuel fine filter (main circuit): number of units A 2

19 Fuel fine filter (main circuit): number of elements per unit A 1

20 Fuel fine filter (main circuit): particle retention A 0.005mm

21 Fuel fine filter (main circuit): pressure differential, max. L bar

12. GENERAL OPERATING DATA

1 Cold start capability: air temperature R 5°C(w/o starting aid, w/o preheating) - (case A)

2 Additional condition (to case A): R 5°Cengine coolant temperature

3 Additional condition (to case A): lube oil temperature R 5°C

4 Additional condition (to case A): lube oil viscosity R 30SAE

9 Cold start capability: air temperature R 0°C(w/o starting aid, w/ preheating) - (case C)

10 Additional condition (to case C): R +40°Cengine coolant temperature

11 Additional condition (to case C): lube oil temperature R -10°C

12 Additional condition (to case C): lube oil viscosity R 15W40SAE

13 Cold start capability: air temperature R -15°C(w/ starting aid, w/ preheating) - (case D)

14 Additional condition (to case D): R +40°Cengine coolant temperature

15 Additional condition (to case D): lube oil temperature R -15°C

16 Additional condition (to case D): lube oil viscosity R 10W40SAE

21 Coolant preheating, heater performance (standard) R 9.0kW

22 Coolant preheating, preheating temperature (min.) R 32°C

28 Breakaway torque (without driven machinery) R 1500Nmcoolant temperature +5°C

30 Breakaway torque (without driven machinery) R 1200Nmcoolant temperature +40°C

29 Cranking torque at firing speed (without driven machinery) R 825Nmcoolant temperature +5°C

31 Cranking torque at firing speed (without driven machinery) R 600Nmcoolant temperature +40°C

96 Starting is blocked if the engine coolant temperature is 5°Cbelow

93 Run-up period to rated speed R 6sec(with driven machinery)(* at general conditions)

MTU Friedrichshafen








37 High idling speed, max. (static) L 1/min

38 Limit speed for overspeed alarm / emergency shutdown L 18001/min

42 Firing speed, from R 801/min

43 Firing speed, to R 1201/min

44 Engine coolant temperature before starting L 60°Cfull-load operation, recommended min.(for emergency/standby sets with coolantpreheating: at least the preheating temperature)

48 Minimum continuous load R 20%

50 Engine mass moment of inertia R 8.4kgm2(without flywheel)

51 Engine mass moment of inertia R 14.08kgm2(with standard flywheel)

55 Load application sequence (1st load stage) R sec(seconds after start command)(* at additonal conditions)

56 Load application sequence (2nd load stage) R sec(seconds after start command)(* at additional conditions)

57 Load application sequence (3rd load stage) R sec(seconds after start command)(* at additional conditions)

58 Load application sequence (1st load stage) R %(% of engine continuous power)(* at additional conditions)

59 Load application sequence (2nd load stage) R %(% of engine continuous power)(* at additional conditions)

60 Load application sequence (3rd load stage) R %(% of engine continuous power)(* at additional conditions)

94 Additional conditions*: engine preheated, R kgm2transient speed droop max. -10%,plant mass moment of inertia, min.

69 Speed droop (with electronic governor) adjustable, from R 0%

70 Speed droop (with electronic governor) adjustable, to R 7%

95 Number of starter ring-gear teeth on engine flywheel 182

13. STARTING (electric)

1 Starter, rated power (make BOSCH) (standard design) R 2X7.5kW

12 Starter, rated power (make DELCO) (standard design) R 2X9.0kW

2 Starter, rated voltage (standard design) R 24V=

4 Starter, power requirement max. (make BOSCH) R A

14 Starter, power requirement max. (make DELCO) R 2600A

5 Starter, power requirement at firing speed R A(make BOSCH)

15 Starter, power requirement at firing speed R 1000A(make DELCO)

6 Recommended battery capacity A 450Ah/20h(automotive starter battery, DIN 72311)

7 Recommended battery capacity (NiCd battery) A Ah/ 5h

MTU Friedrichshafen








8 Recommended battery capacity A 240Ah/ 5h(NiCd battery, VDE 0108)

16 Start attempt duration (engine preheated) R 3sec

17 Start attempt duration (engine not preheated) R sec

18 Start attempt duration, max. L 30sec

15. STARTING (pneumatic starter)

5 Starting air pressure before starter motor, min. R 17bar

6 Starting air pressure before starter motor, max. R 30bar

7 Starting air pressure before starter motor, min. L 17bar

8 Starting air pressure before starter motor, max. L 30bar

18 Start attempt duration (engine preheated) R 3sec

19 Start attempt duration (engine not preheated) R sec

20 Start attempt duration, max. L sec

21 Air consumption / start attempt (engine preheated) R 0.84mn3

22 Air consumption / start attempt (engine not preheated) R mn3

23 Starting air tank for 3 start attempts R 110liter(max. 40 bar) (engine preheated)






29 Starting air tank for 3 start attempts R liter(max. 40 bar) (engine not preheated)






16. INCLINATIONS - STANDARD OIL SYSTEM (ref.: waterline)

15 Longitudinal inclination, continuous max. L 12*degreedriving end down(Option: max. operating inclinations)

16 Longitudinal inclination, temporary max. L degreedriving end down(Option: max. operating inclinations)

17 Longitudinal inclination, continuous max. L 12*degreedriving end up(Option: max. operating inclinations)

MTU Friedrichshafen








18 Longitudinal inclination, temporary max. L degreedriving end up(Option: max. operating inclinations)

19 Transverse inclination, continuous max. L 25*degree(Option: max. operating inclinations)

20 Transverse inclination, temporary max. L degree(Option: max. operating inclinations)

27 Longitudinal inclination, continuous max. L degreedriving end down(Option: max. replenishment period)

28 Longitudinal inclination, temporary max. L degreedriving end down(Option: max. replenishment period)

29 Longitudinal inclination, continuous max. L degreedriving end up(Option: max. replenishment period)

30 Longitudinal inclination, temporary max. L degreedriving end up(Option: max. replenishment period)

31 Transverse inclination, continuous max. L degree(Option: max. replenishment period)

32 Transverse inclination, temporary max. L degree(Option: max. replenishment period)

18. CAPACITIES

1 Engine coolant capacity (without cooling equipment) R 160liter

10 Intercooler coolant capacity R 40liter

11 On-engine fuel capacity R 7liter

14 Engine oil capacity, initial filling R 260liter(standard oil system)(Option: max. operating inclinations)

15 Engine oil capacity, initial filling R liter(standard oil system)(Option: max. replenishment period)

20 Oil change quantity, max. R liter(standard oil system)(Option: max. operating inclinations)

21 Oil change quantity, max. R liter(standard oil system)(Option: max. replenishment period)

28 Oil pan capacity, dipstick mark min. L 160liter(standard oil system)(Option: max. operating inclinations)

29 Oil pan capacity, dipstick mark max. L 200liter(standard oil system)(Option: max. operating inclinations)

30 Oil pan capacity, dipstick mark min. L liter(standard oil system)(Option: max. replenishment period)

31 Oil pan capacity, dipstick mark max. L liter(standard oil system)(Option: max. replenishment period)

19. WEIGHTS / DIMENSIONS

9 Engine weight, dry R 5650kg(basic engine configuration acc. toscope of supply specification)

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10 Engine weight, wet R 6090kg(basic engine configuration acc. toscope of supply specification)

21. EXHAUST EMISSIONS

307 Regulation: TA-Luft (Edition 1986) - CP G --mg/mn3

Nitric oxide (NOx) (5% O2)


Carbon monoxide (CO) (5% O2)


Unburned hydrocarbons (HC)


Dust (5% O2)


Formaldehyde (5% O2)

311 Regulation: stationary power plants in France - CP G --mg/mn3

Nitric oxide (NOx) (5% O2)


Carbon monoxide (CO) (5% O2)


Unburned hydrocarbons (NMHC)


Dust / particulates (5% O2)

316 Regulation: US EPA "non-road" G --g/kWh(40 CFR 89 - stage I -)Nitric oxide (NOx)

365 Regulation: US EPA "non-road" G --g/kWh(40 CFR 89 - stage I -) NOx-40%Nitric oxide (NOx)

317 Regulation: US EPA "non-road" G --g/kWh(40 CFR 89 - stage I -)Carbon monoxide (CO)

318 Regulation: US EPA "non-road" G --g/kWh(40 CFR 89 - stage I -)Unburned hydrocarbons (HC)

319 Regulation: US EPA "non-road" G --g/kWh(40 CFR 89 - stage I -)Particulates

320 Regulation: US EPA "non-road" G --g/kWh(40 CFR 89 - stage II -)Nitric oxide (NOx) + unburned hydrocarbons (HC)

321 Regulation: US EPA "non-road" G --g/kWh(40 CFR 89 - stage II -)Carbon monoxide (CO)

323 Regulation: US EPA "non-road" G --g/kWh(40 CFR 89 - stage II -)Particulates

141 Exhaust volume flow, dry - CP R 5400m3/h(standard conditions)

143 Exhaust mass flow - CP R 6800kg/h(reference conditions)

144 Residual oxygen content (O2) in dry exhaust - CP R 9.0Vol %(standard conditions)

145 Total combustion calorific value - CP R kW

37 Smoke index, BOSCH FSP R 0.2

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22. ACOUSTICS

101 Exhaust noise, unsilenced CP R 116dB(A)(free-field sound pressure level Lp,1m distance, ISO 6798)

201 Exhaust noise, unsilenced CP R dB(A)(sound power level LW, ISO 6798)

102 Exhaust noise, unsilenced FSP R dB(A)(free-field sound pressure level Lp,1m distance, ISO 6798)

202 Exhaust noise, unsilenced FSP R dB(A)(sound power level LW, ISO 6798)

103 Exhaust noise, unsilenced - FSP (free-field sound-pressure level Lp, 1m distance,ISO 6798)Spectrum No.

203 Exhaust noise,unsilenced - CP (sound power level LW, ISO 6798)Spectrum No.

104 Exhaust noise, unsilenced, Spectrum No. FSP (free-field sound pressure level Lp,1m distance, ISO 6798)

204 Exhaust noise,unsilenced - FSP (sound power level LW, ISO 6798)Spectrum No.

109 Engine surface noise with attenuated intake noise - CP R 107dB(A)(filter) (free-field sound pressure level Lp, 1m distance,ISO 6798)

209 Engine surface noise with attenuated intake noise - CP R dB(A)(filter) (sound power level LW, ISO 6798)

110 Engine surface noise with attenuated FSP R dB(A)intake noise (filter) (free-field sound pressurelevel Lp, 1m distance, ISO 6798)

210 Engine surface noise with attenuated intake noise - FSP R dB(A)(filter) (sound power level LW, ISO 6798)

111 Engine surface noise with attenuated intake noise - CP (filter) (free-field sound pressure level Lp, 1m distance,ISO 6798)Spectrum No.

211 Engine surface noise, Spectrum No. CP with attenuated intake noise (filter)(sound power level LW, ISO 6798)

112 Engine surface noise with attenuated intake noise - FSP (filter) (free-field sound pressure level Lp, 1m distance,ISO 6798)Spectrum No.

212 Engine surface noise, Spectrum No. FSP with attenuated intake noise (filter)(sound power level LW, ISO 6798)

125 Structure borne noise at engine mounting CP brackets in vertical direction above resilientmounts, spectrum No.

126 Structure borne noise at engine mounting FSP brackets in vertical direction above resilientmounts, spectrum No.

129 Test stand impedance spectrum, Diagram No.

130 Test stand impedance spectrum, Diagram No. (cont.)

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23. LOAD PROFILE AND TBO (case A)

15 Maintenance schedule no.

16 Maintenance schedule no. (cont.)

G-DRIVE

QSB1

Displacement : 50.3 litre (3067 in3) Bore : 159 mm (6.25 in.) Stroke : 159 mm (6.25 in.)

No. of Cylinders : 16 Aspiration : Turbocharged and AftercooledEmission Certification : N/A

Curve Number:FR6250

Basic Engine Model:KTA50-G3

Engine Critical Parts List:CPL : 2227

Cummins Inc.Columbus, Indiana 47202-3005

EXHAUST EMISSIONS DATA SHEET

Exhaust Emissions Data @ 1500 RPM

K50

Note: mg/m3 and PPM numbers are measured dry and corrected to 5% O2 content.

Test Methods and Conditions:Steady-State emissions recorded per ISO8178-1 during operation at rated engine speed (+/- 2%) and stated constant load (+/-2%) with engine temperatures, pressures, and emission rates stabilized.

Fuel Specifications:46.5 Cetane Number, 0.035 Wt. % Sulfur; Reference ISO8178-5, 40CFR86.1313-98 Type 2-D and ASTM D975 No. 2-D.

Reference:25°C (77°F) Air Inlet Temperature, 40°C (104°F) Fuel Inlet Temperature, 100 kPa (29.53 in Hg) Barometric Pressure; 10.7 g/kg (75 grains H2O/lb) of dry air Humidity (required for NOx correction): Intake Restriction set to maximum allowable limit for clean filter; Exhaust Back Pressure set to maximum allowable limit.

Data was taken from a single engine test according to the test methods, fuel specification, and reference conditions stated above and is subject to engine-to-engine variability. Tests conducted with alter-nate test methods, instrumentation, fuel, or reference conditions can yield different results.

Data subject to change without notice.

Date:30 JUN 12

Engine Speed Standby Power Prime Power Continuous Power

RPM kWm hpLimited Time Unlimited Time

kWm hpkWm hp kWm hp

1500 1227 1645 1150 1541 1097 1470 900 12061800 1380 1850 1300 1742 1220 1635 1000 1340

Standby Power Prime Power Continuous PowerComponent g/BHP-h mg/m3 PPM g/BHP-h mg/m3 PPM g/BHP-h mg/m3 PPM

HC (Total Unburned Hydrocarbons) 0.13 55 110 0.12 50 100 0.1 42 90

NOx (Oxides of Nitrogen as NO2) 12 6100 2880 11 5500 2590 9 4500 2140

CO (Carbon Monoxide) 2.8 1400 1060 2.7 1400 1020 2.6 1300 930

PM (Particulate Matter) 0.08 40 - 0.09 35 - 0.11 55 -

SO2 (Sulfer Dioxide) 0.12 56 28 0.12 58 26 0.13 56 28

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Gross Engine Power Output - kWm

Litre/hour

1500 RPM

OUTPUT POWER FUEL CONSUMPTION

% kWm BHPkg/

kWm·hlb/

BHP·hlitre/hour

U.S. Gal/hour

STANDBY POWER

100 1227 1645 0.203 0.334 293 77.4

PRIME -- LIMITED TIME RUNNING POWER

100 1150 1541 0.202 0.333 274 72.3

PRIME -- UNLIMITED TIME RUNNING POWER

100 1097 1470 0.202 0.333 261 69.0

75 822 1102 0.206 0.338 199 52.5

50 548 735 0.216 0.355 139 36.6

25 275 368 0.234 0.385 76 20.0

CONTINUOUS POWER

100 900 1206 0.204 0.336 216 57.1

CONVERSIONS: (Litres = U.S. Gal x 3.785) (kWm = BHP x 0.746) (U.S. Gal = Litres x 0.2642) (BHP = Engine kWm x 1.34)

Data shown above represent gross engine performance capabilities obtained and corrected in accordance with ISO-3046 conditions of 100 kPa (29.5 in Hg) barometric pressure [110 m (361 ft) altitude], 25 °C (77 °F) air inlet temperature, and relative humidity of 30% with No. 2 diesel or a fuel corresponding to ASTM D2.

See reverse side for application rating guidelines.The fuel consumption data is based on No. 2 diesel fuel weight at 0.85 kg/litre (7.1 lbs/U.S. gal).Power output curves are based on the engine operating with fuel system, water pump and lubricating oil pump; not included are battery charging alternator, fan, optional

equipment and driven components.

TECHNICAL DATA DEPT. CERTIFIED WITHIN 5% CHIEF ENGINEER

Displacement : 50.3 litre (3067 in3 ) Bore : 159 mm (6.25 in.) Stroke : 159 mm (6.25 in.)

No. of Cylinders : 16 Aspiration : Turbocharged and Aftercooled

CUMMINS ENGINE COMPANY, INC

Columbus, Indiana 47201

ENGINE PERFORMANCE CURVE

Curve Number:

FR-6250Basic Engine Model:

KTA50-G3

Engine Critical Parts List:

CPL: 2227

Date:

12Jan01

PageNo.

Engine SpeedStandby Power

Rating

Prime Power Rating Continuous PowerRatingLimited Time Unlimited Time

RPM kWm BHP kWm BHP kWm BHP kWm BHP

1500 1227 1645 1150 1541 1097 1470 900 1206

1800 1380 1850 1300 1742 1220 1635 1000 1340

Engine Performance Data @ 1500 RPM

These guidelines have been formulated to ensure proper application of generator drive engines in A.C. generator set installations. Generator drive engines are not designed for and shall not be used in variable speed D.C. generator set applications.

STANDBY POWER RATINGApplicable for supplying emergency power for the duration of the utility power outage. No overload capability is available for this rating. Under no condition is an engine allowedto operate in parallel with the public utility at the Standby Power rating. This rating should be applied where reliable utility power is available. A Standby rated engine should be sized for a maximum of an 80% average load factor and 200 hours of operation per year. This includes less than 25 hours per year at the Standby Power rating. Standby ratings should never be applied except in true emergency power outages. Negotiated power outages contracted with a utility company are not considered an emergency.

PRIME POWER RATINGApplicable for supplying electric power in lieu of commercially purchased power. Prime Power applications must be in the form of one of the following two categories:

UNLIMITED TIME RUNNING PRIME POWER

Prime Power is available for an unlimited number of hours per year in a variable load application. Variable load should not exceed a 70% average of the Prime Power rating during any operating period of 250 hours. The total operating time at 100% Prime Power shall not exceed 500 hours per year. A 10% overload capability is available for a period of 1 hour within a 12-hour period of operation. Total operating time at the 10% overload power shall not exceed 25 hours per year.

LIMITED TIME RUNNING PRIME POWER

Limited Time Prime Power is available for a limited number of hours in a non-variable load application. It is intended for use in situations where power outages are contracted, such as in utility power curtailment. Engines may be operated in parallel to the public utility up to 750 hours per year at power levels never to exceed the Prime Power rating. The customer should be aware, however, that the life of any engine will be reduced by this constant high load operation. Any operation exceeding 750 hours per year at the Limited Time Prime Power rating should use the Continuous Power rating.

CONTINUOUS POWER RATINGApplicable for supplying utility power at a constant 100% load for an unlimited number of hours per year. No overload capability is available for this rating.

KTA50-G3 Derate Curves @ 1500 RPM

Reference Standards:BS-5514 and DIN-6271 standards are based on ISO-3046.

0

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20

25

0 500 1000 1500 2000 2500 3000Altitude [Meters]

Der

ate[

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STANDBY

Ambient Temp ºF/ºC 120/50

104/40

77/25

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25

0 500 1000 1500 2000 2500 3000Altitude [Meters]

Der

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LIMITED TIME PRIME

Ambient Temp ºF/ºC 120/50

104/40

77/25

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15

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0 500 1000 1500 2000 2500 3000Altitude [Meters]

Der

ate[

% o

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AmbientTemp ºF/ºC

120/50 104/40 77/25

CONTINUOUS

CURVE NO : FR-6250 DATE : 12Jan01

120/50 104/40

77/25

Ambient Temp ºF/ºC

0

5

10

15

20

25

0 500 1000 1500 2000 2500 3000

Altitude [Meters]

Der

ate[

% o

f R

ated

Po

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PRIME

NOTE: Derates shown are based on 15 in H20 air intake restriction and 2 in Hg exhaust back pressure.

For sustained operation above these conditions, derate by an additional 5% per 1000 ft (300 m) and 9% per 18° F (10° C).

Cummins Engine Company, Inc.Engine Data Sheet

DATA SHEET : DS-6250ENGINE MODEL : KTA50-G3 CONFIGURATION NUMBER : D283021DX02 DATE : 12Jan01

PERFORMANCE CURVE : FR-6250

INSTALLATION DIAGRAM CPL NUMBER • Fan to Flywheel : 3626420 • Engine Critical Parts List : 2227

GENERAL ENGINE DATAType ............................................................................................................................................................... 4-Cycle; 60° Vee; 16-Cylinder DieselAspiration ....................................................................................................................................................... Turbocharged and AftercooledBore x Stroke.............................................................................................................. — in x in (mm x mm) 6.25 x 6.25 (159 x 159)Displacement.............................................................................................................................. — in3

(liter) 3067 (50.3)Compression Ratio........................................................................................................................................ 13.9 : 1

Dry WeightFan to Flywheel Engine.......................................................................................................... — lb (kg) 11820 (5360)Heat Exchanger Cooled Engine............................................................................................ — lb (kg) 12260 (5560)

Wet WeightFan to Flywheel Engine.......................................................................................................... — lb (kg) 12485 (5662)Heat Exchanger Cooled Engine............................................................................................ — lb (kg) 13085 (5934)

Moment of Inertia of Rotating Components • with FW 6009 Flywheel .......................................................................................... — lbm • ft2 (kg • m2) 301 (12.7) • with FW 6017 Flywheel ........................................................................................... — lbm • ft2 (kg • m2) 515 (21.7)Center of Gravity from Rear Face of Flywheel Housing (FH 6024)........................................ — in (mm) 47.5 (1206)Center of Gravity Above Crankshaft Centerline ....................................................................... — in (mm) 11.0 (279)Maximum Static Loading at Rear Main Bearing.......................................................................... — lb (kg) 2000 (908)

ENGINE MOUNTINGMaximum Bending Moment at Rear Face of Block ......................................................... — lb • ft (N • m) 4500 (6100)

EXHAUST SYSTEMMaximum Back Pressure @ Standby Power Rating.................................................... — in Hg (mm Hg) 2 (51)

AIR INDUCTION SYSTEMMaximum Intake Air Restriction • with Dirty Filter Element @ Standby Power Rating ............................................. — in H2O (mm H2O) 25 (635) • with Clean Filter Element @ Standby Power Rating........................................... — in H2O (mm H2O) 15 (381)

COOLING SYSTEMCoolant Capacity — Engine Only................................................................................... — US gal (liter) 42.5 (161)Maximum Coolant Friction Head External to Engine — 1800 rpm................................. — psi (kPa) 15 (103)

— 1500 rpm................................. — psi (kPa) 10 (69)Maximum Static Head of Coolant Above Engine Crank Centerline............................................. — ft (m) 60 (18.3)Standard Thermostat (Modulating) Range................................................................................. — °F (°C) 180 - 200 (82 - 93)Minimum Pressure Cap (For Cooling Systems with less than 2 m [6 ft.] Static Head)........ — psi (kPa) 14 (96)Maximum Top Tank Temperature for Standby / Prime Power ................................................. — °F (°C) 220 / 212 (104 / 100)

LUBRICATION SYSTEMOil Pressure @ Idle Speed.................................................................................................... — psi (kPa) 20 (138)

@ Governed Speed ......................................................................................... — psi (kPa) 50 - 70 (345 - 483)Maximum Oil Temperature.......................................................................................................... — °F (°C) 250 (121)Oil Capacity with OP 6024 Oil Pan : High - Low .............................................................. — US gal (liter) 40 - 32 (151 - 121)Total System Capacity (Including Bypass Filter).............................................................. — US gal (liter) 46.7 (177)Angularity of OP 6024 Oil Pan — Front Down ..................................................................................... 30°

— Front Up .......................................................................................... 30°— Side to Side..................................................................................... 30°

FUEL SYSTEMType Injection System........................................................................................................................................................... Direct Injection Cummins PTMaximum Restriction at PT Fuel Injection Pump — with Clean Fuel Filter............................................. — in Hg (mm Hg) 4.0 (102)

— with Dirty Fuel Filter................................................ — in Hg (mm Hg) 8.0 (203)Maximum Allowable Head on Injector Return Line (Consisting of Friction Head and Static Head)....... — in Hg (mm Hg) 6.5 (165)Maximum Fuel Flow to Injection Pump.................................................................................................. — US gph (liter / hr) 165 (625)

ELECTRICAL SYSTEMCranking Motor (Heavy Duty, Positive Engagement) ........................................................................................................ — volt 24Battery Charging System, Negative Ground ............................................................................................................... — ampere 35Maximum Allowable Resistance of Cranking Circuit......................................................................................................... — ohm 0.002Minimum Recommended Battery Capacity

• Cold Soak @ 50 °F (10 °C) and Above ............................................................................................................. — 0°F CCA 1280• Cold Soak @ 32 °F to 50 °F (0 °C to 10 °C)...................................................................................................... — 0°F CCA 1800• Cold Soak @ 0 °F to 32 °F (-18 °C to 0 °C)....................................................................................................... — 0°F CCA 1800

COLD START CAPABILITYMinimum Ambient Temperature for Aided (with Coolant Heater) Cold Start within 10 seconds................................ — °F (°C) 50 (10)Minimum Ambient Temperature for Unaided Cold Start............................................................................................... — °F (°C) 45 (7)

PERFORMANCE DATAAll data is based on: • Engine operating with fuel system, water pump, lubricating oil pump, air cleaner and exhaust

silencer; not included are battery charging alternator, fan, and optional driven components.• Engine operating with fuel corresponding to grade No. 2-D per ASTM D975.• ISO 3046, Part 1, Standard Reference Conditions of:

Barometric Pressure : 100 kPa (29.53 in Hg) Air Temperature : 25 °C (77 °F)Altitude : 110 m (361 ft) Relative Humidity : 30%

Steady State Stability Band at any Constant Load ................................................................................................................— % +/- 0.25Estimated Free Field Sound Pressure Level of a Typical Generator Set; Excludes Exhaust Noise; at Rated Load and 7.5 m (24.6 ft); 1800 rpm / 1500 rpm....................................................... — dBA 94.6 / 92.4Exhaust Noise at 1 m Horizontally from Centerline of Exhaust Pipe Outlet Upwards at 45° — 1800 / 1500 rpm.....— dBA 126 / 125

STANDBY PRIME POWERPOWER UNLIMITED TIME

60 hz 50 hz 60 hz 50 hz

Governed Engine Speed..............................................................— rpm 1800 1500 1800 1500Engine Idle Speed ....................................................................... — rpm 725 - 775 725 - 775 725 - 775 725 - 775Gross Engine Power Output...........................................— BHP (kWm) 1850 (1380) 1645 (1227) 1635 (1220) 1470 (1097)Brake Mean Effective Pressure.......................................... — psi (kPa) 265 (1827) 283 (1951) 235 (1620) 253 (1744)Piston Speed.................................................................— ft / min (m / s) 1875 (9.5) 1562 (7.9) 1875 (9.5) 1562 (7.9)Friction Horsepower ......................................................... — HP (kWm) 225 (168) 155 (116) 225 (168) 155 (116)Engine Water Flow at Stated Friction Head External to Engine:

• 4 psi Friction Head........................................... — US gpm (liter / s) 535 (33.7) 440 (27.8) 535 (33.7) 440 (27.8)• Maximum Friction Head.................................. — US gpm (liter / s) 470 (29.6) 400 (25.2) 470 (29.6) 400 (25.2)

Engine Data with Dry Type Exhaust ManifoldIntake Air Flow ................................................................— cfm (liter / s) 3900 (1840) 3700 (1746) 3700 (1746) 3400 (1605)Exhaust Gas Temperature......................................................— °F (°C) 887 (475) 977 (525) 860 (460) 968 (520)Exhaust Gas Flow ..........................................................— cfm (liter / s) 9100 (4295) 8500 (4011) 8400 (3964) 7900 (3728)Air to Fuel Ratio .....................................................................— air : fuel 26.5 : 1 27.0 : 1 27.5 : 1 28.0 : 1Radiated Heat to Ambient .....................................— BTU / min (kWm) 10000 (176) 8500 (150) 8500 (150) 7300 (130)Heat Rejection to Coolant ......................................— BTU / min (kWm) 51000 (900) 44000 (775) 44000 (775) 38500 (680)Heat Rejection to Exhaust......................................— BTU / min (kWm) 53000 (935) 48000 (845) 47000 (830) 43000 (760)

ENGINE MODEL : KTA50-G3DATA SHEET : DS-6250

DATE : 12Jan01CUMMINS ENGINE COMPANY, INC. Columbus, Indiana 47202-3005 CURVE NO. : FR-6250

N.A. - Data is Not AvailableN/A - Not Applicable to this EngineTBD - To Be Determined



APPENDIX 2: COMMISSIONING PLAN

VERSION 2 19 FEBRUARY 2020

Commissioning Plan

Prescribed Premises Categories 12 and 52 Crushing and Screening of Material and

Power Generation

SAVANNAH PROJECT

PREPARED BY:

Commissioning Plan | Prescribed Premises Categories 12 & 52

2020 02 19_WA Commissioning Plan_Final V2 II

Table of Contents 1. INTRODUCTION ..................................................................................................................................... 3

1.1 COMMISSIONING STAGES AND TIMESCALE ............................................................................................. 3 1.2 COMMISSIONING PHASES ..................................................................................................................... 4 1.2.1 Mobile Crushing and Screening Plant ................................................................................................ 4 1.2.2 Expansion of Power Generation Infrastructure ................................................................................... 4

2. IMPACTS AND MANAGEMENT ................................................................................................................ 5

2.1 EMISSIONS TO AIR ................................................................................................................................ 5 2.2 NOISE EMISSIONS ................................................................................................................................ 8 2.3 DISCHARGE TO LAND AND WATER ......................................................................................................... 9

3. MONITORING ...................................................................................................................................... 11

4. MANAGEMENT OF ACCIDENTS AND MALFUNCTIONS ............................................................................ 12

5. REPORTING ........................................................................................................................................ 13

Tables Table 1: Proposed Construction, Development and Commissioning Schedule ......................................... 3

Table 2: Air Emission Sources, Receptors, Impacts and Control Measures ............................................. 5

Table 3: Noise Emission Sources, Receptors, Impacts and Control Measures ......................................... 8

Table 4: Discharge to Land and Water Sources, Receptors, Impacts and Control Measures ................... 9

Table 5: Commissioning Monitoring Plan ................................................................................................ 11

Table 6: Contingency Plan ...................................................................................................................... 12


2020 02 19_WA Commissioning Plan_Final V2 3

1. INTRODUCTION This Commissioning Plan supports a Works Approval application submitted to the Department of Water and Environmental Regulation (DWER) in February 2020 by Savannah Nickel Mines Pty Ltd (SNM), a wholly owned subsidiary of Panoramic Resources Limited (Panoramic). It has been prepared in accordance with the Works Approval which requests approval to undertake the following under the Environmental Protection Act 1986 and Environmental Protection Regulations 1987:

• Category 12: Screening, etc. of material: premises (other than premises within category 5 or 8) on which material extracted from the ground is screened, washed, crushed, ground, milled, sized or separated (50,000 tonnes or more per year). It is proposed waste rock will be processed through a mobile crushing and screening plant to be situated on the upper surface of the South Waste Rock Dump (SWRD). Up to 500,000 tonnes (~300,000 m3) per annum of crushed waste rock will be used by WBHO Infrastructure Pty Ltd (WBHO) and Main Roads Western Australia (MRWA) for site maintenance purposes which triggers Category 12.

• Category 52: Electric power generation: premises (other than premises within category 53 or an emergency or standby power generating plant) on which electrical power is generated using a fuel (10 megawatts or more in aggregate (using a fuel other than natural gas)). Additional power generation infrastructure is required to meet current and future power generation requirements of the Project and ensure a safe working environment for underground personnel. This includes expansion of auxiliary power generators at the primary vent fan (located adjacent to the pit) and an increase in power generation from the existing power station (located adjacent to the processing plant and fuel farm). The total power generation from these facilities will total 25 MW (maximum capacity).

Commissioning shall be carried out by SNM in accordance with this Commissioning Plan.

1.1 Commissioning Stages and Timescale The Project will be constructed, developed and commissioned in two stages as per the indicative dates shown in Table 1.

Table 1: Proposed Construction, Development and Commissioning Schedule

Stage Construction Component Month of Works Commencement

Month of Works Completion

1 Construct a mobile crushing and screening plant on the upper surface of South Waste Rock Dump (SWRD).

Quarter 1 and 2 (2020) Quarter 1 and 2 (2020)

2 Construct additional power generation infrastructure adjacent to the open pit in the primary vent fan area comprising of the installation of: • diesel generators. • double skinned fuel tanks. • high and low voltage

transformers. • high voltage switches. • cable trays. • fuel piping.

Infrastructure in place. Retrospective approval

request.

Infrastructure in place. Retrospective approval

request.



1.2 Commissioning Phases

1.2.1 Mobile Crushing and Screening Plant The commissioning process for the mobile crushing and screening plant will have the following phases: 1. Pre-commissioning – comprising static checks on unpowered equipment to confirm that the infrastructure

has been built according to specification. 2. Wet commissioning – comprising test operation of equipment and facilities with water and fuel. 3. Ore/rock commissioning – comprising test operation of equipment and facilities with ore/rock, water and fuel.

Material feeds of ore/rock will be gradually increased until they reach the steady-state design volumes. 4. Compliance report – submission of a compliance report to demonstrate infrastructure has been built and

installed in accordance with the Works Approval.

1.2.2 Expansion of Power Generation Infrastructure The commissioning process for the additional power generation infrastructure will have the following phases: 1. Pre-commissioning – comprising static checks on unpowered equipment to confirm that the infrastructure

has been built according to specification. 2. Wet commissioning – comprising test operation of ‘empty’ equipment and facilities with the addition of fuel. 3. Compliance report – submission of a compliance report to demonstrate infrastructure has been built and

installed in accordance with the Works Approval.



2. IMPACTS AND MANAGEMENT Potential impacts associated with the mobile crushing and screening plant and the additional power generation infrastructure in relation to air, noise and discharge to land and water are summarised in the following sub-sections along with appropriate control measures.

2.1 Emissions to Air Sources, possible receptors, potential impacts and control measures for emissions to air during the commissioning phase are shown in Table 2.

Table 2: Air Emission Sources, Receptors, Impacts and Control Measures

Source Possible Receptors Potential Impacts Control Measures Likelihood Consequence Risk Mobile Crushing and Screening Plant Emissions to air associated with crushing and screening activities are expected to predominately comprise of dust particles (Total Suspended Solids), as well as combustion products from associated mobile equipment (SOx and NOx). The sources of these emissions include: • Activities involved with the

handling and transport of materials, ore/rock crushing and screening.

• Emissions from the combustion of diesel by surface mobile equipment and light and heavy vehicles.






• Decline in vegetation health through dust smothering vegetation.

Combustion Emissions: • Generators and diesel engines

will be maintained and serviced on a regular basis and according to the manufacturer’s specifications to ensure efficient running, optimum fuel consumption and minimised emissions (Commitment 1).

• Low sulfur diesel will be used in equipment and generators (Commitment 2).

• Emissions from mining and associated activities will be detailed in the National Pollutant Inventory (NPI) Report and National Greenhouse and Energy Report (NGER) submitted annually (Commitment 3).

Dust Emissions: • Construction and commissioning

activities will not be undertaken


Low



Source Possible Receptors Potential Impacts Control Measures Likelihood Consequence Risk during periods of strong wind (Commitment 4).

• Surface mobile equipment and light and heavy vehicles will keep to designated roads (Commitment 5).

• Vehicle speed limits will be applied to reduce dust generation from vehicle movements (Commitment 6).

• The generation of fugitive dust emissions will be minimised using a combination of water sprays, misters and water carts (Commitment 7).

• Regular inspections will be undertaken to evaluate the effectiveness of point source dust control measures. Corrective action will be implemented where necessary (Commitment 8).

• Crushing and screening activities will not be undertaken during periods of strong wind (Commitment 9).

• Occupational hygiene requirements will be complied with in operational areas (Commitment 10).

Expansion of Power Generation Infrastructure Power generation will produce greenhouse gas emissions including approximately 172,000 kg/year of NOx.



communities comprise


• Vehicles and power generation equipment will be maintained to minimise emissions (Commitment 11).

• Dust suppression measures will be implemented as necessary


Low



Source Possible Receptors Potential Impacts Control Measures Likelihood Consequence Risk Power generation will produce fugitive particulate emissions, notably PM10 and PM2.5. Fugitive dust emissions may be generated during construction and installation of power generation infrastructure.

Frog Hollow Aboriginal Community (10 km), Mabel Downs Homestead (25 km) and Warmun (40 km).


during construction (Commitment 12).



2.2 Noise Emissions Sources, possible receptors, potential impacts and control measures for noise emissions during the commissioning phase are shown in Table 3.

Table 3: Noise Emission Sources, Receptors, Impacts and Control Measures

Source Possible Receptors Potential Impacts Control Measures Likelihood Consequence Risk Mobile Crushing and Screening Plant • Processing activities

(crushing, grinding, conveying).

• Construction and earthwork activities.

• Mobile and static equipment noise from engines.

• Road noise from surface mobile equipment and light and heavy vehicles.





• Compliance with the Environmental Protection (Noise) Regulations 1997 (Commitment 13).

• All vehicles and plant equipment will be regularly maintained to ensure they are operating efficiently and are not unduly noisy. (Commitment 14).

• Where possible, mufflers and other noise attenuating equipment will be installed and maintained on plant, vehicles and equipment so as to reduce exposure to occupational noise (Commitment 15).

• Standard PPE will used by employees where required to reduce exposure to occupational noise (Commitment 16).

Possible Slight Low

Expansion of Power Generation Infrastructure • Construction and

earthwork activities. • Mobile and static

equipment noise from engines.





• As above. Possible Slight Low



2.3 Discharge to Land and Water Sources, possible receptors, potential impacts and control measures for discharge to land and water during the commissioning phase are shown in Table 4.

Table 4: Discharge to Land and Water Sources, Receptors, Impacts and Control Measures

Source Possible Receptors Potential Impacts Control Measures Likelihood Consequence Risk Mobile Crushing and Screening Plant Spillage, leakage and seepage of hydrocarbon contaminants associated with accidents, breakdowns or malfunctions from surface mobile equipment, light and heavy vehicles.

• Employees. • Soil. • Flora, fauna and

vegetation. • Surface water. • The closest off-site



• Groundwater is unlikely to be affected considering the SWRD is located high in the landscape on a ridgeline and is situated over 30 m above the nearest watercourse in the valley floor (Mine Creek).

• Surface mobile equipment, heavy and light vehicles will carry spill kits and be inspected and maintained on a regular basis (Commitment 17).

• Heavy and light vehicle maintenance will be undertaken in designated workshop areas located on concrete pads constructed so that they drain to a clean water recovery system. Where maintenance activities occur outside of these areas, hydrocarbon spillages and leakages will be captured and appropriately managed through the use of drip trays and hydrocarbon absorbent materials (Commitment 18).

• Soil contaminated by hydrocarbons will be treated in-situ, at the bioremediation pad or transported offsite to a controlled waste licenced facility for treatment (Commitment 19).

• Storage of hydrocarbons will be undertaken in accordance with existing approvals (Commitment 20).

Possible Slight Low

Expansion of Power Generation Infrastructure Spillage, leakage and seepage of hydrocarbons associated with accidents, breakdowns or malfunctions from power generation equipment

• Soil. • Surface water. • Flora, fauna and

vegetation. • Groundwater.


• Soil contaminated by hydrocarbons will be treated in-situ, at the bioremediation pad or transported offsite to a controlled waste licenced facility for treatment (As above).

Possible Slight Low



Source Possible Receptors Potential Impacts Control Measures Likelihood Consequence Risk including generators, fuel tanks, transformers and fuel piping.

• The closest off-site communities comprise Frog Hollow Aboriginal Community (10 km), Mabel Downs Homestead (25 km) and Warmun (40 km).

• Existing areas have been heavily compacted through extensive ongoing use over a period of years.

• Groundwater is unlikely to be affected considering the primary vent fan area is located high in the landscape adjacent to the open pit.

• Storage of hydrocarbons will be undertaken in accordance with existing approvals (As above).



3. MONITORING A monitoring plan for the commissioning phases of the Project is provided in Table 5. Monitoring data will be reviewed by a competent person as soon as it is available to identify any trends of concern.

Table 5: Commissioning Moni toring Plan

Aspect Frequency/Format Mobile Crushing and Screening Plant Dust. Daily inspection logbooks. Inspections and maintenance of surface mobile equipment, light and heavy vehicles.

Daily pre-start check and maintenance log books.

Hydrocarbon spills to ground and clean-up. Incident report form as required. Ore/rock and water input volumes. Daily/monthly logbooks. Expansion of Power Generation Infrastructure Air/dust/greenhouse gas emissions. Diesel usage.

Monthly fuel usage inventory. Annual National Pollutant Inventory (NPI) reporting. Annual National Greenhouse and Energy (NGER) reporting.

Inspections and maintenance of power generation equipment including generators, fuel tanks, transformers and fuel piping.

Daily/monthly logbooks.

Hydrocarbon spills to ground and clean-up. Incident report form as required.



4. MANAGEMENT OF ACCIDENTS AND MALFUNCTIONS

Contingencies for the commissioning phase for the Project is summarised in Table 6. A register of exceptions, incidents and corrective actions during commissioning will be maintained.

Table 6: Cont ingency Plan

Contingency Action Mobile Crushing and Screening Plant Spill, leak or seepage of hydrocarbon contaminants from surface mobile equipment, light and heavy vehicles.

Shut down, recover spill, identify fault and repair. Dispose of hydrocarbon contaminated absorbents. Soil contaminated by hydrocarbons to be treated in-situ, at the bioremediation pad or transported offsite to a controlled waste licenced facility for treatment.

Dust suppression or collection systems not working correctly.

Identify fault and repair.

Excessive dust from stockpiling or crushing. Increase rate of water application from sprinklers or water carts. Plant noise exceeds workplace standards outside of designated hearing protection zones.

Investigate cause and remedy to comply with workplace standards.

Expansion of Power Generation Infrastructure

Spill, leak or seepage of hydrocarbons from power generation equipment including generators, fuel tanks and fuel piping.

Shut down, recover spill, identify fault and repair. Dispose of hydrocarbon contaminated absorbents. Soil contaminated by hydrocarbons to be treated in-situ, at the bioremediation pad or transported offsite to a controlled waste licenced facility for treatment.



5. REPORTING Written advice will be provided to DWER with regards to:

• Commencement of commissioning (two calendar days prior to start).

• Completion of commissioning (seven calendar days after completion). A commissioning report will be submitted to DWER following completion of commissioning. This report will include the following:

• A list of any original monitoring reports submitted to Savannah from third parties for the commissioning period.

• A summary of the environmental performance of the infrastructure as installed, against the design specification set out in the Works Approval.

• A review of performance against the Works Approval conditions.

• Where Works Approval conditions have not been met, measures proposed to meet the design specification and/or Works Approval conditions, together with timescales for implementing the proposed measures.

works approval prescribed premises categories 12 and 52 ... · illustrates the south waste rock...

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