1

IN THE MATTER of the Resource Management Act 1991

AND

IN THE MATTER of a submission and further submissions by TrustPower Limited on the Proposed Canterbury Land and Water Regional Plan

STATEMENT OF EVIDENCE OF PETER BRYAN LILLEY ON BEHALF OF TRUSTPOWER LIMITED

1 INTRODUCTION

1.1 My full name is Peter Bryan Lilley.

1.2 I am TrustPower Limited's ("TrustPower") Engineering Manager, a position that is responsible for, amongst other things, the optimisation and enhancement of TrustPower's hydro-electric generation and irrigation assets and the development of new schemes. Prior to this position, I was employed as the Hydro-Development Manager and was responsible for the hydraulic and safety performance of the various dams and structures within TrustPower's hydro-electric generation portfolio.

1.3 I am also currently TrustPower's Acting Environmental Manager. In this position, I am responsible for TrustPower's environmental portfolio, which sees me managing TrustPower's interest in resource consent applications, district and regional plans/policy statements, legislation, Treaty of Waitangi matters, environmental compliance and hazardous substance programmes.

1.4 I hold the qualification of Bachelor of Engineering (Civil) from the University of Auckland (1989) specialising in the areas of catchment hydrology, river hydraulics and water resource engineering. I am a member of the Geotechnical Society, the International Society of Rock Mechanics, and the New Zealand Society of Large Dams on which I am the current vice

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chairman. I am also on the ICOLD Committee (International Commission on Large Dams) on Public Safety around Dams.

1.5 Prior to joining TrustPower in June 2000, I was an Associate of Riley Consultants Limited, a firm comprising specialist Water Resources and Geotechnical engineering consultants. My experience over this time consisted of safety evaluations of dam and associated structures, hydrological analysis and scheme optimisation and enhancement investigations.

1.6 Within the Canterbury region, over the past 10 years I have been involved in a range of irrigation and generation enhancement options including development of the Highbank Pump Station (completed in 2010) which supplies water to Barrhill Chertsey Irrigation Limited ("BCI"). I also have an active role in providing strategic and technical assistance to ongoing workstreams being undertaken within the framework of the Canterbury Water Management Strategy ("CWMS").

2 SCOPE OF EVIDENCE

2.1 This statement of evidence address the following matters:

(a) Overview of TrustPower's electricity generation operations.

(b) TrustPower's interest in Canterbury Region.

(c) Specific overview of the Project.

(d) TrustPower's interest in, and submission on, the Proposed Canterbury Land and Water Regional Plan ("Proposed Plan").

3 OVERVIEW OF TRUSTPOWER

3.1 TrustPower is a home grown, privately owned, company which is a predominantly New Zealand owned (more than 90% of its shares are owned by the Tauranga Energy Consumer Trust and Infratil). TrustPower has its origins in the Tauranga Electric Power Board, which was established in 1924. TrustPower was formed pursuant to the Energy Companies Act 1992, as part of the deregulation of the electricity supply industry.

3.2 Until 1999, TrustPower was a vertically integrated company (that is, it had generation, local transmission, and retail interests) with a regional focus.

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3.3 Following the 1999 electricity industry reforms (introduced by the Electricity Industry Reform Act 1998), TrustPower sold its local transmission business and grew its generation and retail operations. In this respect, TrustPower's customer base has grown from 50,000 to 220,000, while its annual generation output has increased from approximately 300 GWh to 2,500 GWh. Today, TrustPower is the nation's fifth largest retailer and fifth largest generator.

Generation Philosophy and Current Generation Portfolio

3.4 Three key features of TrustPower's generation philosophy and portfolio distinguish it from New Zealand's other large generators:

(a) a commitment to small to medium hydro generation and wind generation;

(b) a commitment to local supply; and

(c) a commitment to the use of renewable resources.

3.5 Nationally, TrustPower now owns and operates a portfolio of 36 hydro-electric power stations and two wind farms. These facilities occupy substantial areas of land, a number of which are both located and effectively managed within environmentally sensitive areas, including within National Parks.

3.6 All generation schemes have two primary descriptive factors. The first is the installed capacity of the scheme which is expressed in MW (megawatts) and is the maximum amount of energy that the scheme can produce at any given time. The second factor is the output of the scheme, expressed in MWh or GWh (megawatt hours or gigawatt hours). This is a measure of the total amount of energy that the scheme produces in a given period, usually a year.

3.7 In terms of scale, TrustPower's hydro schemes vary from 0.43 MW / 3.7 5GWh at Kaniere Forks (enough to supply the electricity needs of about 470 homes) to 101 MW / 215 GWh at the Waipori Scheme (about 27,000 homes), and are distributed throughout New Zealand. Appendix 1 contains a figure which highlights the location of the company's generation assets. The table in Appendix 2 summarises the key attributes of TrustPower's generation assets.

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3.8 Overall, I believe TrustPower's emphasis on moderate, renewable and local generation places TrustPower squarely in line with the sustainable management purpose of the Resource Management Act 1991 ("RMA").

4 TRUSTPOWER'S INTEREST IN THE CANTERBURY REGION

4.1 Within the Canterbury Region, TrustPower owns and operates the Coleridge Hydro-Electric Power Scheme ("Coleridge HEPS"), and the Montalto and Highbank Power Stations. The location of these schemes is marked on the map attached as Appendix 3 to this evidence.

4.2 Cumulatively, these three power stations have an installed generation capacity of approximately 69 MW and generate approximately 355 GWh per year. This is equivalent to providing sufficient electricity to power approximately 44,000 households.

The Coleridge HEPS

4.3 The Coleridge HEPS officially commenced operation in 1914. The Coleridge HEPS is owned and operated by TrustPower and has an annual energy production capacity of approximately 260 GWh per year.

4.4 The Coleridge HEPS is situated between Lake Coleridge and the River (Appendix 3). It utilises natural lake storage, augmented by canals containing diverted inflows from the Harper and Wilberforce Rivers (at the western end of the lake catchment) and the Acheron River via Coleridge Stream (at the eastern end of the catchment). Water from the lake travels down two intake tunnels on the south-eastern shore of the lake to the Coleridge HEPS, located adjacent to the .

4.5 A 3 m high constructed dam and gate across Lake Stream at the northern- western end of the lake is used (in combination with the HEPS intakes) to control the operating levels for the lake between 505.6 m and 509.4 m above mean sea level. The control gate on Lake Stream, which when open allows lake outflow via Lake Stream, is only permitted to open if required due to circumstances beyond the control of the consent holder. In normal operating conditions, the diversions are managed to ensure that all water is discharged via the intake and tunnels to the Coleridge HEPS.

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4.6 During normal operation of the Coleridge HEPS, approximately 26 m3/s on average is drawn from Lake Coleridge. TrustPower is permitted to divert up to 40.1 m3/s of water from Lake Coleridge into the Coleridge HEPS. Water diverted from the lake is fed directly to the Coleridge HEPS and its five generating turbines. The tailrace below the Coleridge HEPS enables water to be discharged into a side braid of the Rakaia River.

4.7 The station is operated in response to demand for energy and inflows to the lake. During the autumn and winter when inflows are typically lower, additional water is supplied out of storage to meet energy demand resulting in the lake level being lowered over its operating range. During the spring and summer, in response to higher inflows and lower energy demand, the lake level will typically rise or be maintained at higher levels.

4.8 In addition to the HEPS, the lake supplies water to the local Coleridge Village via the existing intake and tunnels.

The Montalto / Highbank Power Stations and the Rangitata Diversion Race

4.9 TrustPower owns and operates the Montalto Hydro-Electric Power Scheme ("Montalto HEPS") and the Highbank Hydro-Electric Power Scheme ("Highbank HEPS") which are located on the Rangitata Diversion Race ("RDR"). The RDR is a 67 km long race system that provides water for the irrigation of 66,000 hectares of land between the Rangitata and Rakaia Rivers. Three irrigation distribution schemes connect to the RDR (Mayfield Hinds, Valetta and Ashburton Lyndhurst).

4.10 The Montalto HEPS is located on the RDR, approximately 16 km from the intake on the . The Montalto HEPS was commissioned in 1982 and utilises the natural fall in the RDR for the generation of electricity. The station has an installed capacity of 1.9 MW.

4.11 The Highbank HEPS is located at the terminus of the RDR. Outflows from the Highbank HEPS represent the only major inflow to the Rakaia River below the , and the RDR is strategically important infrastructure for irrigation development on the (south of the Rakaia River). The Highbank HEPS utilises water not required for irrigation or stockwater to generate hydro-electricity.

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4.12 The Highbank HEPS currently has an installed capacity of 28 MW and generates between 75 and 130 GWh of electricity per annum. Water from the Highbank HEPS is discharged to a braid of the Rakaia River via a 1.2 km long tailrace. Due to the variable draw off of water for irrigation, which can vary significantly within and between seasons, the generation from Highbank can vary significantly over short periods and on a year to year basis with extended periods of no generation, and hence no discharge, occurring during most irrigation seasons. Despite this variability, the energy contribution from Highbank is still significant on a regional basis as it is heavily weighted to the high energy demand winter months.

4.13 The resource consents authorising the operation of the Highbank HEPS and Montalto HEPS are held by Rangitata Diversion Race Management Limited ("RDRML"). TrustPower is a shareholder in RDRML. The resource consents were granted by the Canterbury Regional Council ("ECan") between 2005 and 2007.

4.14 TrustPower is part way through its Highbank Pumping Station project. The first stage was the construction of the Highbank Pumping Station, which was completed in 2010. The completed stage of the Highbank Pumping Station project involves taking/diverting of up to 6 m3/s of water allocated to the BCI Scheme from the Rakaia River via a new intake structure, settling pond and canal adjacent to the Highbank HEPS and tailrace as shown in Appendix 4. It is expected that the Highbank Pumping Station will progressively expand, through the addition of further pumps, to a capacity of 8 to 9 m³/s over the next few years.

4.15 Water that is taken / diverted from the Rakaia River is pumped up the penstocks of the Highbank HEPS and into the RDR race network via a purpose built 7 MW Pumping Station. Once the water is in the RDR it can be conveyed for distribution to irrigators associated with BCI. The Highbank Pumping Station only operates during the irrigation season (ie 10 September to 9 May each year) and does not affect the generation capacity of the Highbank HEPS.

5 SPECIFIC OVERVIEW OF THE LAKE COLERIDGE PROJECT

5.1 In addition to the above, TrustPower has a programme of actively pursuing renewable electricity generation and irrigation opportunities throughout New Zealand. In particular, TrustPower looks for new development or

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enhancement opportunities close to its existing electricity generation infrastructure. With respect to the Canterbury Region, in 2011 TrustPower sought a variation to the National Water Conservation (Rakaia River) Order 1988 ("Rakaia WCO") to enable the future consenting, construction and operation of the Lake Coleridge Project.

5.2 The Lake Coleridge Project involves augmenting the use of the Coleridge HEPS in a staged manner so that water stored in Lake Coleridge is able to be utilised for irrigation reliability on the Canterbury Plains (north and south of the Rakaia River) and additional hydro-electricity generation.

5.3 In particular, the Lake Coleridge Project enables water stored in Lake Coleridge during defined flow conditions to be exempt from the minimum flow and flow sharing restrictions in the Rakaia WCO upon its subsequent release and use for irrigation.

5.4 Reliability will be improved without compromising the Rakaia WCO flow restrictions, as the stored water released from Lake Coleridge can only be taken by contracting parties listed on the register:

(a) at times when those parties could otherwise not exercise their consents (ie because the river's flow is below the minimum flow restriction); and

(b) without that stored water being subject to the Rakaia WCO's 1:1 flow sharing requirement.

5.5 Stored water can be used by those contracting parties in accordance with the process set out in agreements with TrustPower. A contracting party will need to vary its resource consent to take water so as to expressly allow them to take stored water when the Rakaia WCO would otherwise prevent such taking. A key aspect of the Lake Coleridge Project is a proposed canal starting from Lake Coleridge, running along the true left bank of the Rakaia River, and finishing in the vicinity of the Highbank HEPS. The canal will link Lake Coleridge to the irrigation areas and infrastructure already constructed in earlier stages. The majority of supply is therefore via a canal rather than the Rakaia River and as such up to 25 m3/s of water will flow down the canal rather than down this stretch of the river, while still ensuring that the values and characteristics set out in the Rakaia WCO will be recognised and sustained.

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5.6 The Lake Coleridge Project will deliver considerable benefits to the Canterbury region. It is expected to initially support up to 45,000 Ha of irrigation at very high levels of reliability. Once integrated into wider Canterbury irrigation infrastructure, the area supported could exceed 65,000 Ha and be as much as twice this area. The estimated benefits of increased reliability of water for irrigation alone are estimated to be around $476.9 million per year from the sale of additional agricultural produce. In terms of energy generation, the Lake Coleridge Project will have, in addition to the existing generation, a combined generation capacity of approximately 30 MW and an annual generation output of 130 GWh. The additional capacity provided via the new generation stations would have enhanced ability to target periods of high energy demand and provide firming capacity for potential wind developments in the Canterbury region. It will also provide water to the irrigated areas at higher elevations, reducing pumping cost and providing the opportunity for pressurised supply.

5.7 In October 2012, ECan Commissioners issued their decision on TrustPower's application to vary the Rakaia WCO. The Commissioners recommended to the Minister for the Environment that the variation be approved. TrustPower is currently awaiting the Minister's decision.

6 TRUSTPOWER'S INTEREST IN THE PROPOSED PLAN

6.1 TrustPower's interests in the Proposed Plan stem primarily from its ownership and operation of the Coleridge HEPS and the Highbank / Montalto Power Stations, and the Company's development aspirations in the region.

6.2 Given the considerable investment made in its generation assets, TrustPower seeks to ensure that their continued operation is not unduly compromised or adversely affected by changes to the relevant policy framework.

6.3 Against the above background, TrustPower has a close interest in the development of objectives, policies and methods potentially impacting on its existing or future developments within the Canterbury region.

Changes in environmental flow regimes

6.4 One of the primary concerns for TrustPower is the effect of any changes in environmental flow regimes on its existing assets. For example, the Coleridge HEPS is effectively limited by the Rakaia WCO controls which govern the contribution of water from the Harper and Wilberforce Rivers to

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Lake Coleridge and the Coleridge HEPS. Under the Proposed Plan the Rakaia WCO limits are used as the environmental flow regime for the Rakaia River. TrustPower supports that flow regime.

6.5 However, Policy 4.4 on its face has the potential to result in changes being made to the environmental flow regimes if it were considered that the environmental flow regime set under the Rakaia WCO did not prioritise allocation in the manner contemplated by Policy 4.4. Any change that reduces flow available to TrustPower would have significant economic consequences.

6.6 Because the value of generation is inherent within resource consents, any reduction in take equates to a direct generation loss. The effects of reduced take would not only affect TrustPower directly in an economic sense, but would put increased pressure on other generation providers, and would potentially adversely affect / derogate those existing consent holders' consents which rely on the operation of generation schemes.

6.7 Accordingly, any change in the Proposed Plan's policy framework which may result in the environmental flow regime for the Rakaia River and its tributaries moving away from the framework set out in the Rakaia WCO is opposed. Accordingly, TrustPower supports the changes to Policy 4.4 suggested by Mr Turner.

Irrigation season

6.8 Policy 4.67 provides that water abstracted for irrigation is managed so that winter flows are available for abstraction to storage, while ensuring ecosystem recovery. Secondly, it states that irrigation abstractions are for the summer (September – April) irrigation season – unless specified otherwise.

6.9 This Policy currently states that only winter flows will be available for storage. It ignores an essential element of the Lake Coleridge Project - the storage of water at all times of the year when flow is available to be abstracted into Lake Coleridge. Flow may well be high at periods during the summer months, and this water will accordingly be stored.

6.10 One of the major benefits of using Lake Coleridge as irrigation storage is the high level of inflow reliability throughout the year. Peak inflows typically occur in late spring and early summer, within the irrigation season, which can be

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stored for use later in the season when river flows are typically under pressure.

6.11 The Lake Coleridge storage can therefore be effectively used more than once during an irrigation season. Firstly the storage can be full at, or near, the beginning of the season to provide security of supply through the early months of the irrigation season. During this period, additional inflow will top up or refill storage being used and hence provide on-going supply throughout the season.

6.12 Policy 4.67 as drafted inhibits the ability to manage the storage in Lake Coleridge dynamically throughout the irrigation and winter season. This reduces the potential level of security and supply area the storage can service and hence additional storage facilities would have to be provided with associated cost and environmental impacts. Accordingly, TrustPower supports the changes to Policy 4.67 suggested by Mr Turner.

Avoidance of adverse effects

6.13 The Proposed Plan introduces a "no adverse effects" theme in several of its policies, particularly those policies concerning land use activities, discharges of contaminants, and the take, use, damming and diversion of water. This requirement is strongly opposed by TrustPower. Practically speaking, this is entirely unachievable, based on TrustPower's previous experience, as the development of any scheme will inevitably result in some adverse effects. When identifying a potential generation scheme, TrustPower will work with its expert team to ensure that the effects of any proposal are appropriately avoided, remedied and mitigated. However, "no adverse effects" is simply unattainable.

6.14 In particular, it contradicts the ability to achieve integrated development. To achieve integrated infrastructure means that there will be times / locations where specific adverse effects are induced. This is done with the realisation that the overall development package is the most appropriate. To attempt to avoid a specific impact will compromise the integrity of the wider development and may well result in an overall increase in adverse effects.

6.15 The Section 42A Report recommends that the "no adverse effects" wording employed by several policies be replaced as that phrase is "too restrictive"

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and "unachievable".1 This has been replaced by "no more than a negligible adverse effect". While it is intended that this replacement wording provides more flexibility, it is TrustPower's position that this new qualification still presents a high threshold and is unworkable. Mr Turner comments on this further in his evidence and TrustPower supports the changes he suggests.

Controlled activity status and investment certainty

6.16 Rule 5.132 of the Proposed Plan specifies that the use of a structure in the bed of a river associated with a lawfully established hydro-electricity generation scheme is a controlled activity. However, it does not provide for the associated damming of water in the bed of a river or the associated alteration, maintenance and operation of structures, or for structures within the beds of lakes as controlled activities. TrustPower and other generation companies place significant investment in their hydro-generation schemes. Certainty is a critical component to justify that investment. As mentioned by Mr Turner, unless the activity as a whole is controlled, the proposed wording simply does not provide investment certainty. On top of that, improvements in efficiencies and the reconsenting of schemes in the future will inevitably affect investment certainty.

6.17 The Section 42A Report recommends that Rule 5.132 be amended to include the "use and maintenance" of structures on the bed of rivers. While the inclusion of "maintenance" is an improvement on the notified version, the Rule as currently worded in the Section 42A Report, is opposed by TrustPower. Not only will this Rule affect investment certainty as discussed above, but it has severe practical implications. Given the similarities in potential environmental effects from activities forming part of an integrated hydro-generation scheme, these activities should all be afforded controlled activity status. Yet under this Rule, there would be no clear benefit for any owner of a lawfully established hydro-electricity generation scheme as any application would consist of multiple activities which would be bundled together with the most restrictive activity classification applying, with the result that an application would likely be processed and assessed as a discretionary activity. The use of discretionary activity status means there is potential for existing activities to be declined. As such the decommissioning of the scheme would need to be considered. As a practical solution, TrustPower

1 Policies 4.41, 4.52

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supports the amendments to Rule 5.132 that Mr Turner has suggested in his evidence.

7 CONCLUSION

7.1 The Coleridge HEPS and the Highbank and Montalto Power Stations are of significant value to TrustPower, the Canterbury region, and to New Zealand. They are a source of renewable generation that assists in providing a secure supply of electricity.

7.2 While TrustPower has a number of concerns with Proposed Plan, we consider these can be alleviated through implementation of the changes recommended by TrustPower's experts.

Peter Lilley 4 February 2013

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TRUSTPOWER GENERATION GROUP ORGANISATION FEB 2012

GROUP UNIT GWh/yr REGION Capacity FILE SETS Gross Total YEAR CONNECT WITH CODE DAMS LAKE Station MW (10yr rolling) MW GWhr/yr Factor GXP Nr Head Flow Type COM'D Name Type Height Crest lth Hazard Name Type Area Vol (m) (cumecs) Large dams bolded (m) (m) Rating (Ha) (1000m3) CENTRAL 310.7 1199.6 Ruahihi 18 165.3 49.8% TGA0331 2 82 28 VFS 1981 Embedded Powerco KMI McLaren Falls CA 23 M McLaren D 9.7 250 Ruahihi Canal E 15 M H 3.8 120 Lower Mangapapa 5.6 TGA0331 1 32 22 HFI 1979 Embedded Powerco KMI Matariki CA 26 M Matariki D 15.2 290 Lloyd Mandeno 14 TGA0331 2 150 12 VFS 1972 Embedded Powerco KMI Mangaonui E 29 130 M Mangaonui D 8 300 KMI Dry Gully E 15 65 H 4 >50 Kaimai 5 0.3 TGA0331 1 10 3.5 VKI 1994 Embedded Powerco KMI Nil Nil Nil Nil Nil R Nil Nil Matahina 80 273.7 39.1% MAT1101 2 76 133 VFS 1967 Grid Transpower MAT Matahina E 86 400 H Matahia W 248 55,100 Hinemaiaia A1 1.36 29.6 50.4% WRK0331 1 32 5.6 HFI 1952 Embedded Unison HMA HA CA/CG 12 105 L HA D 21.7 Hinemaiaia A2 1.04 1 32 4.5 HFS HMA HA CA/CG 12 105 L HA D 21.7 Hinemaiaia B 1.5 WRK0331 1 25 8.2 HFIDE 1966 Embedded Unison HMA HB CB/CG 22 100 M HB R 12.1 584 Hinemaiaia C 2.8 WRK0331 1 35 10.5 HFS 1981 Embedded Unison HMA HC CA/CG 27 L HC R 0.3 50 Wheao 24 111 48.5% ROT1101 2 126 24 VFS 1984 Embedded Transpower WHE Rangitaiki Canal CG 11 50 L H 0.1 232 Flaxy 2.1 ROT1101 1 32 8 HFIDE 1984 Embedded Transpower FLX Flaxy Dam E 11 160 L Flaxy D 239 Flaxy Canal/Pond E 10 200 H 160 Tararua I & II 67 270 46.0% BPE0331 51 Nil Nil WTG 1999 Embedded Powerco TWF Nil Nil Nil Nil Wind Nil Nil LTN0331 52 Nil Nil WTG 1999 Embedded Powerco TWF Nil Nil Nil Nil Wind Nil Nil Tararua III 93 350 43.0% TWC2201 31 Nil Nil WTG 2007 Grid Transpower TWC Nil Nil Nil Nil Wind Nil Nil 149 TARANAKI 41.655 41.655 149.4 Patea 32.2 108.2 38.4% HWA1101 4 58 65 UFS 1984 Grid Transpower PTA Patea E 82 150 H Rotorangi W 617 144,000 Mangorei 4.5 18.5 46.9% CST0331 4 76.5 7 HFS 1906-31 Embedded Powerco MGR Mangamahoe E/C 24 160 H Mangamahoe D 38 850 Motukawa 4.8 21.9 52.1% HUI0331 3 98 7 HFS 1924 Embedded Powerco MTK Ratapiko E 12 65 L Ratapiko D 1312 Motukawa II 0.155 0.8 58.9% 1 4.5 3.2 KVI 2005 Embedded Powerco MTK2 MK2 E/G 6 7.5 L Head Pond H 0.45 0.75 12 COLERIDGE 65.8 348.1 Coleridge 39 254.3 74.4% COL0661 5 149 42 HFS 1914-28 Grid Transpower COL Lake Stream Radial Gate Wo/St 5 L Coleridge M 3,686 36,856 Highbank 25 93.8 42.8% ASB0661 1 104 26.5 VFS 1945 Embedded Ashburton HBK Nil Nil Nil Nil L Head Pond I / R 300 Montalto 1.8 ASB0661 1 7 31 HKI 1958 Embedded Ashburton MOO Nil Nil Nil Nil L Head Pond I / R 300 7 COAST 63.53 336.9 Arnold 3 25.3 96.3% DOB0661 2 14 29 VFS 1932 Embedded Westpower ALD Arnold E/CG/CA 13 80.77 M Arnold Reservoir R/H 4200 1,000 Kumara 6.5 47.9 54.7% KUM0661 1 78 10 HFS 1978 Embedded Westpower KUM Nil E Dillmans Tailrace R 18 28 Dillmans 3.5 KUM0661 1 46 10 HFS 1978 Embedded Westpower DLM Kapitea Long Dam E 16 900 H Kapitea D 220 7,200 DLM Kapitea Short Dam E 14 195 H Kapitea D 220 7,200 Loopline E 4.5 185 L Kumara 1,000 Duffers 0.5 60.7% KUM0661 1 13 5.8 HFIDE 1980 Embedded Westpower DFS Canal/Head Pond E 11 150 L R/H 125 McKays Creek 1.1 10.8 HKK0661 1 33 5 VFS 1931 Embedded Westpower MKY Minor E L Kaniere M 20 22,810 Kaniere Forks 0.43 HKK0661 2 76 1 HPS 1911 Embedded Westpower KNF Minor Wo/We L Kaniere M 20 22,810 Wahapo 3.1 15.3 56.3% HKK0661 1 29 12 HFS 1990 Embedded Westpower WAH Minor C/We >5 L Head Pond H 2.5 20 Argyle (Branch) 3.8 49 50.9% ARG1101 1 21 20 HFS 1983 Grid Transpower ARG Branch CB 15 (Max) M Argyle Head Pond D 22 468 Wairau (Branch) 7.2 ARG1101 1 42 20 HFIDE 1983 Grid Transpower WAU Nil - 10 L Wairau Head Pond H >100 Waihopai 2.4 10.9 51.8% BLN0331 2 43.6 10 VFS 1926/95 Embedded MARL WOP Waihopai CA 33 55.5 M Waihopai River R Gravel Cobb 32 177.7 63.4% COB0661 6 596 7.36 HPS 1944 Grid Transpower COB Cobb E 38 204 H Cobb Reservoir W 210 19 OTAGO 137.85 379.9 Waipori 1A 10 173.9 23.7% HWB0331 1 33.5 42 VKS 1983 Embedded Delta WPI Mahinerangi CA 35 H Mahinerangi M 2000 242,000 Waipori 2A(3/2/1) 58 HWB0331(2A3) And/or BWK1101 3 223.5 37 VFS 1967-76 Part Emb DEL / XPWR WPI Nr 2 Weir CA 12 M H 320 Waipori 3 7.6 BWK1101 1 50.3 18 VFS 1953 Grid Tanspower WPI Nr 3 Weir CG 10.7 L R 10000? Waipori 4 8 BWK1101 1 56.7 20 VFS 1954 Grid Tanspower WPI Nr 4 Dam CA 18.9 L Edgar H 376 Deep Stream A 3 23.2 44.1% HWB0331 1 136 5 HFS 2008 Embedded Delta WPI Main Dam E 25 350 M Reservoir H 27 1905 Saddle Dam E 12 215 M Reservoir 27 1200 Dam C E 10 60 L Head Pond >1 Deep Stream B 3 23.2 HWB0331 1 151 5 HFS 2008 Embedded Delta WPI Nil Nil Nil Nil L R Paerau 10 54.6 50.9% NSY0331 2 137 9 HFS 1984 Embedded OPL PRU Paerau E M Paerau I / R 39 Patearoa 2.25 NSY0331 1 31 9 HFIDE 1984 Embedded OPL PTR Nil E M I / R 6

Mahinerangi 36 105 33.3% HWB0331 12 Nil Nil WTG 2011 Embedded Delta MWF Nil Nil Nil Nil Wind Nil Nil 11 Australia 98.7 389 Snowtown 98.7 389 45.0% 47 Nil Nil WTG 2008 Grid Electranet Nil Nil Nil Nil Wind Nil Nil 47 No stations 40 2803 GWhr/yr 245 sets Legend: D ouble E nded Legend: A rch Legend: H igh Legend: D ays F rancis B uttress M edium H ours Details MW GWh MW % Energy % CF H orozontal C oncrete L ow I rrigation Total 718 2803 100% 100% 45% I nduction E arth M onths Hydro 424 1689 59.0% 60.3% 46% K aplan G ravity R un of river Wind 295 1114 41.0% 39.7% 43% P elton We ir W eeks S ynchronous Wo od V ertical St eel W ind T urbine G enerator

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