Energy Data File July 2005
Energy Data File July 2005
E. Gas Figure E.1: Gas Flows for March Year 20051 By gross production:
FIELDS By net production:
5.1%
4.5%
63.7%
16.7%
0.6%
McKee
Mangahew a
Mau i
Kapuni
Ngatoro 2
4.9%
65.8%
15.1%
0.1%
5.4%
Todd Taranaki 100%
PRODUCERS Operator: Todd Taranaki
Shell Explo 38.75% EPIL 20.00% Shel l (Petro ) 18.75% OMV 10.00% Todd Energy 6.25% TOPC 6.25%
Shel l (Petro ) 50% Todd Energy 50%
Operator: Shel l Todd Oil Servi ces
Operator: Shel l Todd Oil Servi ces
WHOLESALER
The Crown
0.2%
Greymouth 87% Southern 9% Greymouth Petro 4%
Operator: Greym outh Pe tro
EGCL
Ngatoro Gas Storage Pro j ect
EFNZL
6.1%
3.1%
Kaimi ro
TAWN
Rimu 3
0.1%
5.5%
3.1%
Greymouth 100%
Southern Petro 96.76% Sw i ft Energy 3.24%
Sw ift Energy 100%
Operator: Sw ift Energy
Operator: Sw ift Energy
Operator: Greym outh Petro
Contact Energy
Genesis Pow er
NGC
TRANSMITTERS (high press ure)
DISTRIBUTORS (low pressure)
RETAILERS
Pow erco, Vector Genesis Energy4
NGC, Nova Gas, W anganui Gas, Others5
Contact Energy
Major users supplied directl y from the transm i ssion system
CONSUMERS
By consumpti on: (c alc ulated)
Users supplied from distributi on systems
New Zealand Steel Carter Ho l t Harvey Degussa Perox i de Fonterra Co-operati ve Todd Energy/ Kiw i Cogeneration NZ Re fi nery Company Southdown Cogeneration Tasman Pulp and Paper and som e other com pan i es
Methanex Ot her indus t ry , commerc ial, res idential, t ransport (as CNG )
42.9%
Chemical methanol manufacture
24.4%
Ball ance AgriNutri ents (Kapun i) Lim i ted
Contact Energy Genesi s Power
Ammonia/urea manufacture
Electric ity generation
4.9%
27.8%
The arrows portray significant flows of gas ownership up to the wholesale/transmission stage. They portray the physical and/or ownership flow of gas from the distribution stage onwards. Company names are listed without the suffixes “Limited” and “New Zealand Limited” where applicable. EFNZL is Energy Finance New Zealand Limited, EGCL is Energy Gas Contracts Limited, EPIL is Energy Petroleum Investments Limited (owned by Shell Investments NZ Limited), Greymouth is Greymouth Petroleum Acquisition Company Ltd, Greymouth Petro is Greymouth Petroleum Limited, KGCL is Kapuni Gas Contracts Limited, NGC is NGC New Zealand Limited, OMV is OMV New Zealand Limited, Shell Explo is Shell Exploration NZ Limited, Shell (Petro) is Shell (Petroleum Mining) Company Limited, Southern is Southern Petroleum (Ohanga) Limited, Southern Petro is Southern Petroleum (New Zealand) Exploration Limited, Swift Energy is Swift Energy New Zealand Limited, TAWN is Tariki, Ahuroa, Waihapa and Ngaere, Todd Energy is Todd Petroleum Mining Company Limited, Todd Taranaki is Todd Taranaki Limited, TOPC is Taranaki Offshore Petroleum Company of New Zealand (owned by Shell Oil Company of the United States). Net production is calculated as gross production less reinjected, flaring, own use, losses and LPG extracted. Notes: 1 Ownership as at 31 March 2005 and excludes LPG. 2 Includes Goldie well. 3 Includes Kauri well. 4 From October 2004, Genesis Energy (retailer) has delivered gas to major users supplied directly from the transmission system. 5 Others include Mercury Energy, Bay of Plenty Electricity, E Gas and Auckland Gas Company.
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Section E: Gas
Energy Data File July 2005
Overview of New Zealand’s Gas Industry
All statistics in this commentary apply to the year ended March 2005, and comparisons apply to that year relative to the year ended March 2004, unless otherwise specified. Overall comments are related to actual and proposed developments in the gas industry as at July 2005.
Ownership Reform of the gas industry began in 1987 when the Crown publicly floated 30% of Petrocorp, through which the Government had managed its interests in the production, transmission and distribution of gas. The Government’s remaining interest in Petrocorp, including the Natural Gas Corporation Limited (NGC), was sold in 1988. The Australian Gas Light Company (AGL) became a majority owner (66.05%) of NGC after it bought Fletcher Challenge Energy (FCE)’s share. In October 2004, AGL sold its 66.05% interest in the North Island’s major gas pipeline company, NGC Holdings Ltd, to Auckland-based energy networks company Vector Limited. In July 2004, Australian company Origin Energy bought a 51.2% stake in Wellington-based Contact Energy from Californian-based Edison Mission Energy. Two petroleum mining permits (PMPs) were granted by Crown Minerals during 2004 and two PMPs have been granted during the first half of 2005. There are now 16 petroleum mining (production) permits in New Zealand. On 8 October 2004, a 155.8 sq-km offshore permit was granted over the Pohokura field. The field operator, Shell Todd Oil Services, has indicated (June 2004) mean hydrocarbon reserves of 700 Bcf gas and 42.8 mmbbls of condensate. Pohokura joint venture partners are Shell Exploration NZ Ltd (48.00030%), OMV NZ Ltd (25.99985%) and Todd Pohokura Ltd (25.99985%). This reflects changes to the permit endorsement effective from 7 July 2005. In September 2004, a 5.99 sq-km onshore PMP for the production of gas and condensate was granted over the Kahili field in the Taranaki Basin. The Kahili joint venture partners are Austral Pacific Energy Ltd (20% and operator), Tap New Zealand Pty Ltd (30%), International Resource Management Corporation (25%) and Millennium Oil and Gas Ltd (25%). In April 2005 a 35.24 sq-km petroleum mining permit, straddling both onshore and offshore areas in the south Taranaki region, was granted for the production of oil and gas from the Kauri field. This permit lies immediately to the south of the existing Rimu PMP (granted in early 2002). Swift Energy New Zealand Limited is the permit operator and holds 100% of the permit equity. PMP documents indicate reserves of up Section E: Gas
to 233 Bcf of gas and 15 mmbbls of oil. In May 2005 a 22.48 sq-km PMP was granted over the Radnor field in the onshore Taranaki basin. The Radnor joint venture partners are Bridge Petroleum (66.67% and operator) and Westech Energy New Zealand (33.33%). Permit documents indicate proven plus probable reserves of 20 Bcf and 0.8 mmbbls. This permit was granted as a result of good flow rates obtained from the Radnor-1 well drilled in the third quarter of 2004. (Source: Various issues of New Zealand Petroleum News – Ministry of Economic Development).
Exploration and Development The 18-month period from 1 January 2004 through to 30 June 2005 saw a substantial increase in gas exploration and development activities. During 2004 a total of 32 wells were drilled (including side tracks and a well abandoned at shallow depth). A total of approximately 73,800 m were made in oil and gas wells, a large increase on the 2003 figure of approximately 35,200 m from 16 wells. Of the 32 wells drilled in 2004, 15 were exploration wells, and 17 were appraisal or development wells. Discoveries were made on two of the exploration wells, indicating a 13% success rate. Figures for the first half of 2005 show that 13 wells (including side tracks) were spudded and it is anticipated that no fewer than eight wells will be drilled in the second half of 2005, bringing the total to at least 21. A majority of wells drilled and planned for 2005 are either appraisal or development wells, although exploration activity remains buoyant. Highlights of drilling campaigns conducted during 2004 and the first half of 2005 included the offshore programme in petroleum exploration permit (PEP) 38460, and subsequent application for a PMP by the joint venture, the large drilling programme completed by Swift Energy in PEP 38719 and the subsequent award of a PMP over the Kauri field, good results from drilling in PEP 38738 (Cheal and Cardiff) and the successful results of the Radnor-1 well (Bridge Petroleum, PEP 38752), which was subsequently granted a PMP in May 2005. Coupled with this increase in drilling activity is an increase in the number and type of seismic acquisition surveys conducted throughout the same 18-month period. A large 3D seismic acquisition vessel was mobilised to New Zealand waters early in the first quarter of 2005 and conducted a multi-permit programme. The third largest onshore 3D seismic survey was conducted by Todd Exploration Limited during the first half of 2005. More 3D seismic data have been acquired during the first half of 2005 than in any other year to date. Substantial development activities during 2004 in91
Energy Data File July 2005
cluded the granting of the Pohokura mining permit and progress on development plans for the Kupe oil and gas field. The drilling of extended reach production wells (from an onshore location) in the Pohokura field commenced during the second quarter of 2005, using the largest onshore rig ever mobilised to New Zealand. The drilling of offshore production wells is scheduled to commence in early 2006. Initial production is expected to be 50 PJ of gas and 3 mmbbls of condensate per annum commencing in late 2006. The Pohokura development is the second offshore hydrocarbon production project to be initiated in New Zealand and the Pohokura platform will be New Zealand’s third offshore production facility, after the Maui A platform (first production in 1979) and the Maui B platform (commissioned in 1992). Australian-based Origin Energy has outlined its proposed developments for the Kupe oil and gas field. Kupe is expected to produce 20 PJ of gas and 1.6 mmbbls of oil per annum when it comes on-stream. Production from the Kupe field is expected to commence in the second quarter of 2007. As part of the industry-led initiative to develop an open access regime for the Maui gas transmission pipeline owned by Maui Development Limited (Shell New Zealand, OMV New Zealand and Todd Energy), an agreement was reached with NGC for the development of an “open access” operating system. Under the agreement, NGC will use a single information platform to operate open access arrangements for both the NGC pipeline system and the 313 km onshore Maui pipeline from the Maui production station in south Taranaki to Huntly power station, south of Auckland. In August 2004, Genesis Energy committed to proceed with the construction of a new gas-fired powerstation. The facility, called e3p (e3p stands for Huntly Energy Efficiency Enhancement Project), is located at Huntly, and is the first major power generation plant using gas to be built for five years. Genesis has entered into longterm contracts for the supply of Kupe, Mangahewa, McKee and Pohokura gas. The $520 million project is one of the largest infrastructure projects currently underway in New Zealand. NGC Holdings Ltd expanded the output at its Kapuni gas treatment plant by almost 55% in the last financial year. In the past year the Kapuni gas treatment plant has been upgraded primarily to process greater quantities of Kapuni gas for the retail market, as well as to receive gas from other sources. As a result of these projects the Kapuni plant will supply an additional 8 PJ of treated gas a year, taking the annual treated gas output to over 22 PJ. LPG production will increase from 35,000 to 40,000 tonnes a year due to improved yields and there has been the addition of a 100-tonne storage vessel. (Source: Various issues of New Zealand Petroleum 92
News – Ministry of Economic Development).
The Government’s package of measures to encourage gas exploration In June 2004, the Government announced a package of measures to encourage gas exploration and development in New Zealand. These were incorporated in the Minerals Programme for Petroleum 2005 which came into effect on 1 January 2005. Amongst the changes introduced by the new Programme are: Royalties 1. Ad Valorem Royalties (AVR) on “discoveries” made between 30 June 2004 and 31 December 2009 (“the period”) as follows: – 1% for gas (was 5%); – 5% for oil (unchanged). 2. Accounting Profit Royalty (APR) of 15% for the first $750,000,000 of gross sales (offshore) for discoveries made during the period (was 20%). 3. APR of 15% for the first $250,000,000 of gross sales (onshore) for discoveries made during the period (was 20%). 4. “Ring Fencing” – all prospecting and exploration costs incurred anywhere in New Zealand (in any permit) during the period will be deductible for the purpose of calculating the APR on a mining permit granted for depleting a discovery made during the period. Costs incurred during the period and prior to the granting of a petroleum mining permit will be allowed to be carried forward for deduction with annual interest at the 10-year Government bond rate +1%. 5. Production from fields that do not qualify as a “Discovery” will pay royalties as per the 1995 Minerals Programme. Other initiatives to promote exploration in New Zealand included the securing of Government backing for a $15 million seismic data acquisition project. A 2D seismic acquisition survey over the central and northern parts of the East Coast Basin (designated Crown Minerals – CM-05) commenced on 26 February and was completed on 13 April 2005. A total of approximately 3,000 km of data was acquired. This basin is under-explored, with only three offshore wells drilled. The CM-05 survey has significantly increased understanding of the oil and gas potential of the East Coast Basin. The data acquired, and the results of subsequent geotechnical studies (conducted by the Institute of Geological and Nuclear Sciences – IGNS), will be released to industry free of charge to encourage further exploration in those areas. Concurrent with these activities, rights to a spec survey shot in 2001 over the Outer Taranaki Basin have been negotiated (6,440 km of 2D seismic data acquired by TGS Nopec and interpretation report by IGNS). The duration of the Northland Blocks Offer was extended Section E: Gas
Energy Data File July 2005
following the successful negotiation of the purchase of approximately 9,000 km of reprocessed 2D seismic data and an accompanying seismic interpretation report (completed by IGNS). Both of these data sets were distributed to interested parties during the second quarter of 2005 in order to support the Outer Taranaki Blocks Offer and the Northland Blocks Offer.
Taxation The so called “183 day rule” was amended during 2004 to the effect that offshore exploration rigs and seismic acquisition ships may work in New Zealand waters for a period of 365 days before operators are liable to pay resident withholding tax.
Kaimiro, owned by Greymouth Petroleum Acquisition Company Limited. Together they provide the remaining 20% of total gas production. (See Chart E.1a.) Figure E.1 presents a schematic of natural gas ownership and physical flows in New Zealand for the March year 2005, with proportions of gas produced by the different fields and consumed by major user/supplier categories. Chart E.1a: Gross Gas Production by Field
Deregulation The gas (and electricity) industries were deregulated in 1993 with the removal of gas franchise areas and the lapsing of wholesale gas price controls (retail price control had already lapsed). In October 2004, the Electricity and Gas Industries Bill, which amends the Gas Act 1992, was passed. The amendments provide for the establishment of an industry body. This body will make recommendations to the Minister on the instigation of arrangements, including rules and regulations for wholesaling, processing, transmission and retailing matters. The Government’s objectives for the gas industry are articulated in the draft Government Policy Statement (GPS) on Gas Governance which was released in October 2004. The Gas Industry Company (GIC) was approved as the industry body in December 2004. The GIC is currently developing its systems and processes to meet the Government’s objectives as outlined in the GPS on Gas Governance.
Production Currently, gas is produced entirely in the Taranaki region, where 11 fields produce gas. New Zealand’s production of natural gas has been dominated by the Maui field. The Maui field and the Kapuni field are owned by Shell Petroleum Mining and Todd Energy. These two fields together provide 80% of total production. They are both operated by Shell Todd Oil Services Limited. Other fields in production during the year to March 2005 were McKee and Mangahewa (from September 2001), owned by Todd Taranaki Limited; the Waihapa/Ngaere and Tariki/Ahuroa fields, owned by Southern Petroleum New Zealand Exploration Limited and Swift Energy New Zealand Limited; Rimu (including Kauri well) owned by Swift Energy New Zealand Limited; Ngatoro (including the Goldie well, which recommenced production in December 2003), owned by Greymouth Petroleum Acquisition Company Limited, Southern Petroleum (Ohange) Limited and Greymouth Petroleum Limited; and Section E: Gas
* Includes the Goldie well. ** Others include Mangahewa and Rimu fields.
As Chart E.1a illustrates, the Maui field was the major source of gas production, providing 63.7% of New Zealand’s gross gas production in the year ended March 2005. The Kapuni field produced 16.7%, Tariki/ Ahuroa 6.0%, Mangahewa 4.5%, McKee 5.1%, Rimu (including Kauri well) 3.1%, Ngatoro (including Goldie well) 0.6%, Kaimiro 0.2%, and Waihapa/Ngaere 0.1% of total gas production. Total New Zealand gas production in the year ended March 2005, excluding gas reinjected or flared and LPG extracted, was 155.6 PJ, a decline of 8.7% compared with 170.4 PJ in the year ended March 2004. This was due to decreases in production at Tariki/ Ahuroa (32%) and Kaimiro (32%), Mangahewa (14%), Waihapa/Ngaere (12%), Maui (11%), and Kapuni (0.1%). There was no gas reinjected for the March year 2004, but there was some (1.0 PJ) for the March year 2005. The Rimu, Ngatoro (including Goldie well) and McKee fields increased their production by 113%, 68% and 18% respectively, compared with the year ended March 2004.
Distribution There are over 3,400 km of high-pressure gas transmission pipelines in New Zealand. The major gas transmission pipelines are NGC’s network and the Maui pipeline, which is owned by Maui Development Limited. Other transmission pipelines are owned by Todd Petroleum and Shell, Todd Taranaki, Swift Energy and Westech Energy. More than 2,800 km of intermediate, medium and low pressure gas distribution pipeline networks in the North Island are connected to the high pressure 93
Energy Data File July 2005
transmission system. NGC also operates extensive gas distribution and retail operations in the North Island of New Zealand. There are five gas distributors: NGC Infrastructure, Nova Gas, Wanganui Gas, Vector and Powerco, and nine retailers: NGC, Nova Gas, Wanganui Gas, Contact Energy (gas wholesaler/retailer), Genesis Energy, Mercury Energy, Bay of Plenty Electricity, E Gas and Auckland Gas Company.
Liquefied petroleum gas In addition to natural gas, the gas industry produced 9.4 PJ of liquefied petroleum gas (LPG) in the year ended March 2005, 8.1% higher than the year ended March 2004 level of 8.7 PJ. Of the 9.4 PJ of production, 0.8 PJ was exported and 8.1 PJ was used in New Zealand. In the year ended March 2005, 0.4 PJ of LPG was imported into New Zealand. LPG statistics are included in the Oil section and are presented in Section D.14.
Compressed natural gas CNG is supplied to the automotive market through North Island service stations. The CNG market has decreased markedly since the removal of government subsidies in 1987. Estimated CNG sales are presented in Section E.5.
End use The three major groups of users of gas in New Zealand are petrochemicals, electricity generation and direct reticulated users, as Chart E.1b (below) illustrates.
Chart E.1b: Gas Use by Sector (March Years)
Petrochemicals The petrochemicals sector used around 29% of New Zealand’s natural gas during the year ended March 2005 (in Methanex’s methanol plants at Motunui and Waitara, and the Ballance Agri-Nutrients (Kapuni) ammonia/urea plant) compared with 26% in the year ended March 2004. Crude methanol is produced from natural gas and then distilled into high (“AA”) grade methanol. Methanex New Zealand produced 120,000 tonnes of methanol during the first quarter 2005 compared with 260,000 tonnes of methanol during the fourth quarter 2004. The reduction of methanol production was due to the closure of Motunui plant as a consequence of natural gas supply constraints. Ballance Agri-Nutrients (Kapuni) Limited (previously Petrochem Limited) manufactures ammonia/urea from natural gas. The ammonia/urea plant uses Maui gas for fuel and a mixture of Maui and Kapuni LTS gas as feedstock.
Electricity generation Gas used for electricity generation (including cogeneration) was about 41% of New Zealand’s natural gas produced during the year ended March 2005. Of the 41% of gas used for generation, 28% was used for electricity generation and 13% was used for cogeneration. Contact Energy Limited (Otahuhu B, Taranaki Combined Cycle and New Plymouth) and Genesis Power Limited (Huntly) are the main thermal electricity generators in New Zealand using natural gas. Gas consumption for electricity generation and cogeneration decreased by 24% and 25% to 41 PJ and 19 PJ respectively, in the year ended March 2005, compared with the year ended March 2004 levels of 55 PJ and 25 PJ respectively.
Reticulated end use The remaining 30% of New Zealand’s gas use was reticulated throughout the North Island (by NGC) through a highpressure pipeline system direct to major users, and to gas utilities for distribution to other industrial users and to the commercial and residential sectors. Of the 44.4 PJ of consumer energy (excluding cogeneration) reticulated in the year ended March 2005, 28.1 PJ (63.3%) was used by industry, 8.9 PJ (20.1%) by the commercial sector, 7.2 PJ (16.1%) by the residential sector and 0.2 PJ (0.5%) in transport
94
Section E: Gas
Energy Data File July 2005
Chart E.1c: Reticulated End Use by Sector
Chart E.4a shows gas demand by direct major users (petrochemicals and electricity generation) and reticulated end use (industrial, commercial, residential and transport) from the March quarter 1974 to the March quarter 2005 and Chart E.4b compares gas demand share for March years 2004 and 2005. Gas demand by petrochemicals and electricity generation was about 104 PJ, 15% lower than the year ended March 2004 level of 123 PJ and gas demand by reticulated end use (including cogeneration) decreased by 4.1% to 63 PJ.
(as CNG), as Chart E.1c (above) illustrates. Annual per capita end use of gas is 10.9 GJ (298 m3). Reticulated demand (observed, excluding cogeneration) increased 8.4% to 44.4 PJ from 41.0 PJ in the year ended March 2004.
Section E: Gas
Chart E.4b shows that in the year ended March 2005 gas demand by direct and reticulated users was 57% and 43% respectively, compared with 60% and 40% in the year ended March 2004. This was mainly due to a decline in gas consumption by Methanex and electricity generation.
95
96
Figure E.2: Gas Flow Summary for March Year 2005 Petajoules (to approximate vertical scale)
PRODUCTION
CONVEYANCE
USE
Gas reinjected 1.0 LPG extracted 9.1 Gas flared and own use 7.2 Fields
Non-energy use Transmission
Kapuni
Maui Development Limited
Mangahewa
Field operators
Maui
Greymouth Petroleum Limited
McKee Ngatoro Rimu
166.5
New Zealand Oil and Gas Services Limited
1
2
Shell Todd Oil Services Limited
Tariki/Ahuroa Waihapa/Ngaere
Direct supply
Methanex New Zealand Limited Ballance Agri-Nutrients (Kapuni) Limited
Natural Gas Corporation of New Zealand Limited (NGC) 149.2
43.7
Electricity generation Direct supply
Swift Energy New Zealand Limited
41.5
149.2
Contact Energy Limited Genesis Power Limited
Todd Petroleum and Shell
Swift Energy New Zealand Limited
18.8
Todd Taranaki Distribution3 Gas distribution companies
Westech Energy
44.4
Cogenerators
Other Industry Uses
28.1
Commercial
8.9
Residential Gross production
Section E: Gas
Notes:
New Zealand Steel Limited Carter Holt Harvey (Kinleith) Contact Energy (Te Awamutu) Degussa Peroxide Limited Fonterra Co-operative NGC, Kapuni Cogeneration Plant New Zealand Refinery Company Limited Southdown Cogeneration Tasman Pulp and Paper Limited Te Rapa Cogeneration Plant Todd Energy/Kiwi Cogeneration
Net production
Calculated 149.2
Statistical difference 0.8
Observed 148.4
1
Includes the Goldie well.
2
Includes the Kauri well.
3
Gas supplied through distribution systems is used by industry (including cogeneration), the commercial, residential and transport sectors. Some cogenerators and other industrial users are supplied directly.
7.2
Transport 0.2
Energy Data File July 2005
Kaimiro
Energy Data File July 2005
E.1 Gross Gas Production by Field* * Includes gas flared, gas reinjected, LPG extracted, own use and losses
Table E.1a: Gross Gas Production by Field1 (PJ) Calendar Year 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Maui
Kapuni
McKee
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 17.87 23.40 32.83 66.49 71.40 96.48 125.79 153.26 148.91 162.41 167.88 165.98 170.98 183.55 176.64 162.31 152.92 173.53 183.76 156.71 186.76 195.67 203.56 186.63 127.35 111.29
4.31 8.21 11.29 13.31 14.06 15.36 40.22 64.35 59.49 29.27 19.12 23.75 30.28 34.74 35.89 40.08 38.60 36.05 42.55 45.98 44.59 46.25 49.04 48.43 51.50 42.84 52.72 46.12 45.43 42.94 34.88 31.99 28.81 27.21 27.79
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.70 2.43 2.98 3.49 3.73 4.56 4.97 5.58 6.19 6.25 7.74 8.83 9.04 9.53 8.92 10.02 9.36 9.38 5.95 6.83 8.18
Waihapa/ Kaimiro/ Ngaere/Piakau2 Moturoa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.31 5.05 3.95 5.63 5.15 1.97 1.22 0.77 0.60 0.63 0.28 0.30 0.28 0.23 0.26
Notes:
1 For definition of terms used see Glossary, Section K. 2 Piakau has not produced gas since September 1999.
Tariki/ Ahuroa
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.18 0.16 0.93 0.72 0.75 0.77 0.59 0.47 0.45 0.39 0.42 0.72 0.72 1.19 1.45 1.16 1.04 0.61 0.47 0.56 0.46 0.33
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5.33 9.91 9.76 10.54 11.35 13.62 14.26 16.31 10.79 3 4
Mangahewa Ngatoro3 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.60 2.44 0.00 0.00 3.22 9.89 8.41 7.98
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.11 0.33 0.42 0.38 0.59 1.29 1.82 1.53 2.01 2.11 1.60 0.83 0.80
Rimu4
Total
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.60 0.82 2.04 3.88
4.31 8.21 11.29 13.31 14.06 15.36 40.22 64.35 59.49 47.14 42.52 56.58 96.76 106.32 133.23 169.24 195.57 189.20 209.45 219.01 217.31 228.31 243.23 237.70 227.84 207.67 243.62 253.43 226.85 253.47 254.17 265.25 248.80 189.66 171.30
Includes Goldie well.
Includes Kauri well.
Chart E.1a1: Annual Gross Gas Production by Field (PJ)
Notes:
1 Includes Kaimiro, Mangahewa, Ngatoro (including Goldie well), Moturoa and Rimu (including Kauri well) fields.
2 Piakau has not produced gas since September 1999.
Section E: Gas
97
Energy Data File July 2005
Table E.1b: Gross Gas Production by Field1 (Mm3) Calendar Year 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Maui
Kapuni
McKee
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 468.1 628.0 879.5 1,773.5 1,876.6 2,499.2 3,224.4 3,901.0 3,783.1 4,113.9 4,247.1 4,199.8 4,307.9 4,610.8 4,407.4 3,998.8 3,719.2 4,218.4 4,456.6 3,778.4 4,517.7 4,775.0 4,992.9 4,555.7 3,082.5 2,693.7
158.0 301.0 414.0 488.0 515.4 565.9 1,502.0 2,346.8 2,175.2 1,077.2 714.4 889.0 1,156.0 1,300.1 1,326.0 1,468.5 1,413.8 1,334.2 1,567.6 1,714.1 1,666.0 1,740.6 1,862.3 1,826.8 1,958.7 1,622.5 1,978.2 1,703.1 1,681.8 1,593.3 1,303.8 1,204.7 1,079.9 1,010.5 1,034.7
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 16.7 57.6 72.1 83.9 88.5 108.8 119.6 136.6 153.3 154.9 191.6 218.7 224.0 236.2 221.0 243.0 228.8 228.0 144.0 165.8 199.3
Waihapa/ Kaimiro/ Ngaere/Piakau2 Moturoa 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 29.3 112.6 88.1 125.5 114.9 43.9 27.2 17.7 15.2 15.4 6.9 7.3 6.9 5.2 6.6
Notes:
1 For definition of terms used see Glossary, Section K.
2 Piakau has not produced gas since September 1999.
New Zealand’s natural gas production has historically been dominated by the Maui field and still accounted for around 65% of New Zealand’s total gas production in the calendar year 2004. Charts E.1a1 and E.2a show gross and net gas production respectively by field from 1970 to 2004. Gross gas production is total gas production after the first separation point. See Figure H.1. Net gas production is the difference between gross gas production and the amount of gas flared, gas reinjected, LPG extracted, own use and losses.
98
Tariki/ Ahuroa
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 4.7 4.2 24.2 18.7 19.5 20.0 15.3 12.1 11.7 10.1 10.8 18.7 18.6 30.9 37.4 30.1 27.6 17.3 14.8 15.3 12.7 15.7 3 4
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 105.9 194.0 191.2 236.5 254.0 310.9 327.2 338.4 239.2
Mangahewa 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 15.1 60.8 0.0 0.0 83.1 255.5 217.4 205.9
Ngatoro3
Rimu4
Total
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 2.1 6.3 8.1 7.5 11.4 24.9 34.6 29.6 39.0 41.7 31.7 16.1 20.0
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.3 0.3 13.7 16.7 44.1 86.8
158.0 301.0 414.0 488.0 515.4 565.9 1,502.0 2,346.8 2,175.2 1,545.2 1,342.4 1,768.5 2,929.5 3,181.4 3,846.0 4,774.5 5,405.6 5,220.8 5,790.0 6,085.2 6,026.8 6,309.4 6,726.8 6,531.7 6,290.8 5,630.4 6,596.0 6,685.0 6,013.0 6,663.3 6,625.1 6,897.1 6,432.9 4,892.8 4,501.8
Includes Goldie well. Includes Kauri well.
Chart E.2a shows that total New Zealand net gas production fell 11% to 154 PJ in 2004, compared with 174 PJ in the year ended December 2003. Overall, the amount of gas flared, gas reinjected, LPG extracted, own use and losses has generally been increasing since around 1978, decreased by 17% from 2002 to 2003 but increased by 6.4% to 17 PJ between 2003 and 2004. Of the total 17 PJ, 47% or 8 PJ relates to the Maui field, 30% or 5 PJ to the Kapuni field and the remaining 23% to the McKee, Kaimiro, TAWN, Mangahewa, Rimu and Ngatoro (including Goldie well) fields. Net gas production for the Kapuni field from 1970 to 1973 has been estimated, assuming that net production was 95% of gross production.
Section E: Gas
Energy Data File July 2005
Table E.1c: Gross Gas Production by Field1 (Bcf) Calendar Year 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Maui
Kapuni
McKee
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 16.53 22.18 31.06 62.63 66.27 88.26 113.87 137.76 133.60 145.28 149.98 148.32 152.13 162.83 155.65 141.22 131.34 148.97 157.38 133.43 159.54 168.63 176.32 160.88 108.86 95.13
5.58 10.63 14.62 17.23 18.20 19.99 53.04 82.88 76.82 38.04 25.23 31.39 40.82 45.91 46.83 51.86 49.93 47.12 55.36 60.53 58.83 61.47 65.77 64.51 69.17 57.30 69.86 60.14 59.39 56.27 46.04 42.55 38.14 35.69 36.54
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.59 2.03 2.55 2.96 3.13 3.84 4.22 4.82 5.41 5.47 6.77 7.72 7.91 8.34 7.81 8.58 8.08 8.05 5.09 5.86 7.04
Waihapa/ Kaimiro/ Ngaere/Piakau2 Moturoa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.03 3.97 3.11 4.43 4.06 1.55 0.96 0.62 0.54 0.54 0.24 0.26 0.24 0.18 0.23
Notes: 1 For definition of terms used see Glossary, Section K. 2 Piakau has not produced gas since September 1999.
Section E: Gas
Tariki/ Ahuroa
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.17 0.15 0.85 0.66 0.69 0.70 0.54 0.43 0.41 0.36 0.38 0.66 0.66 1.09 1.32 1.06 0.98 0.61 0.52 0.54 0.45 0.55 3 4
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.74 6.85 6.75 8.35 8.97 10.98 11.56 11.95 8.45
Mangahewa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.53 2.15 0.00 0.00 2.93 9.02 7.68 7.27
Ngatoro3
Rimu4
Total
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.07 0.22 0.29 0.26 0.40 0.88 1.22 1.04 1.38 1.47 1.12 0.57 0.71
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.48 0.59 1.56 3.06
5.58 10.63 14.62 17.23 18.20 19.99 53.04 82.88 76.82 54.57 47.41 62.46 103.46 112.35 135.82 168.61 190.90 184.37 204.47 214.90 212.84 222.81 237.55 230.66 222.16 198.84 232.94 236.08 212.35 235.31 233.96 243.57 227.18 172.79 158.98
Includes Goldie well. Includes Kauri well.
99
Energy Data File July 2005
E.2 Net Gas Production by Field* * Excludes gas flared, gas reinjected, LPG extracted, own use and losses
Table E.2a: Net Gas Production by Field1 (PJ) Calendar Year 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Maui
Kapuni
McKee
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 10.03 22.42 31.88 64.94 69.93 93.22 121.68 148.07 143.66 156.56 161.42 159.05 163.68 175.68 168.88 154.66 145.62 164.02 172.32 145.87 175.39 184.64 191.49 174.98 118.79 103.34
4.09 7.80 10.73 12.65 10.50 12.13 34.80 57.08 53.93 23.42 9.03 7.97 9.01 10.42 10.04 10.55 13.13 11.23 11.53 11.42 12.21 19.08 18.62 18.60 17.36 18.29 19.56 20.85 20.31 21.79 24.51 24.87 24.84 23.48 22.69
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.69 2.39 2.93 3.42 3.64 4.46 4.88 5.44 6.03 6.08 7.32 8.27 8.60 9.13 7.99 9.25 8.51 8.59 5.43 6.30 7.67
Waihapa/ Ngaere/Piakau2
Kaimiro/ Moturoa3
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.02 4.37 3.50 4.96 4.35 1.78 1.04 0.71 0.43 0.36 0.23 0.24 0.22 0.17 0.19
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.18 0.16 0.93 0.72 0.75 0.77 0.58 0.47 0.45 0.39 0.41 0.72 0.72 1.09 1.36 1.08 0.90 0.52 0.34 0.42 0.36 0.12
Notes: 1 For definition of terms used see Glossary, Section K. 2 Piakau has not produced gas since September 1999. 3 All gas from the Moturoa field was used for own purposes.
Tariki/ Mangahewa Ahuroa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4.78 8.75 8.63 9.38 9.86 11.74 12.37 14.11 8.84
4
5
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.32 2.39 0.00 0.00 3.13 9.77 8.31 7.88
Ngatoro4
Rimu5
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.83 1.13 1.44 1.30 1.19 0.70 0.20
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.41 1.50 3.42
Total 4.09 7.80 10.73 12.65 10.50 12.13 34.80 57.08 53.93 33.45 31.45 39.85 73.95 80.54 104.11 135.56 164.85 159.06 172.50 177.88 177.61 193.02 204.22 198.95 184.41 174.69 199.10 213.43 187.53 218.21 229.70 241.70 229.62 173.72 154.34
All gas from the Ngatoro field was flared from March 1992 to May 1998. The Ngatoro field includes the Goldie well. All gas from the Rimu field was flared from 1999 to 2001.
Chart E.2a: Annual Net Gas Production by Field (PJ)
Notes: Includes Kaimiro, Mangahewa, Moturoa and Ngatoro (all gas from the Ngatoro field was flared from March 1992 to May 1998). The Ngatoro field includes the Goldie well.
1
100
2
Piakau has not produced gas since September 1999.
Section E: Gas
Energy Data File July 2005
Table E.2b: Net Gas Production by Field1 (Mm3) Calendar Year 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Maui
Kapuni
McKee
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 264.0 601.7 854.0 1,732.4 1,838.0 2,414.7 3,119.0 3,768.9 3,649.7 3,965.9 4,083.6 4,024.4 4,123.8 4,413.1 4,213.8 3,810.4 3,541.6 3,987.6 4,179.4 3,517.1 4,242.5 4,505.8 4,696.9 4,271.3 2,875.3 2,501.4
150.1 286.0 393.3 463.6 384.9 446.8 1,299.6 2,081.3 1,971.9 861.6 338.5 298.5 342.2 390.2 371.4 386.5 480.8 415.6 424.9 425.7 456.1 718.1 706.5 701.4 660.3 692.1 734.1 770.0 752.0 808.6 916.4 936.8 931.0 871.8 844.8
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 16.5 56.6 71.1 82.4 86.5 106.5 117.5 133.3 149.4 150.7 181.4 205.0 213.1 226.1 197.9 224.3 207.9 208.8 131.4 152.9 186.9
Waihapa/ Ngaere/Piakau2 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 22.6 97.5 78.1 110.7 97.1 39.8 23.3 16.3 10.9 8.8 5.6 5.8 5.4 3.7 4.7
Kaimiro/ Moturoa3
Tariki/ Mangahewa Ahuroa
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 4.7 4.2 24.1 18.7 19.5 19.9 15.0 12.0 11.6 10.1 10.7 18.7 18.6 28.2 35.1 28.0 24.2 14.6 10.7 11.5 9.9 3.2
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 103.1 188.8 186.1 229.1 239.5 287.6 303.1 309.8 220.8
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 8.0 59.6 0.0 0.0 80.7 252.4 214.9 203.3
Ngatoro4
Rimu5
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 15.5 21.9 27.9 25.2 23.0 13.7 4.8
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 12.6 41.4 81.7
Ngatoro4
Rimu5
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.55 0.77 0.99 0.89 0.81 0.48 0.17
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.45 1.46 2.89
Total 150.1 286.0 393.3 463.6 384.9 446.8 1,299.6 2,081.3 1,971.9 1,125.6 940.3 1,152.5 2,074.6 2,233.0 2,806.7 3,586.2 4,339.4 4,167.2 4,497.1 4,630.9 4,632.8 5,084.3 5,357.2 5,187.2 4,767.8 4,497.0 5,089.4 5,423.6 4,767.2 5,559.3 5,917.7 6,252.6 5,941.8 4,493.4 4,051.7
Table E.2c: Net Gas Production by Field1 (Bcf) Calendar Year 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Maui
Kapuni
McKee
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 9.32 21.25 30.16 61.18 64.91 85.27 110.15 133.10 128.89 140.05 144.21 142.12 145.63 155.85 148.81 134.56 125.07 140.82 147.60 124.21 149.82 159.12 165.87 150.84 101.54 88.34
5.30 10.10 13.89 16.37 13.59 15.78 45.90 73.50 69.64 30.43 11.95 10.54 12.08 13.78 13.12 13.65 16.98 14.68 15.01 15.03 16.11 25.36 24.95 24.77 23.32 24.44 25.92 27.19 26.56 28.56 32.36 33.08 32.88 30.79 29.83
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.58 2.00 2.51 2.91 3.05 3.76 4.15 4.71 5.27 5.32 6.40 7.24 7.53 7.98 6.99 7.92 7.34 7.37 4.64 5.40 6.60
Waihapa/ Ngaere/Piakau2 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.80 3.44 2.76 3.91 3.43 1.40 0.82 0.57 0.39 0.31 0.20 0.21 0.19 0.13 0.17
Notes:
1 For definition of terms used see Glossary, Section K.
2 Piakau has not produced gas since September 1999.
3 All gas from the Moturoa field was used for own purposes.
Section E: Gas
Kaimiro/ Moturoa3 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.17 0.15 0.85 0.66 0.69 0.70 0.53 0.43 0.41 0.36 0.38 0.66 0.66 1.00 1.24 0.99 0.85 0.52 0.38 0.41 0.35 0.11
Tariki/ Mangahewa Ahuroa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.64 6.67 6.57 8.09 8.46 10.16 10.70 10.94 7.80
4
5
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.28 2.11 0.00 0.00 2.85 8.91 7.59 7.18
Total 5.30 10.10 13.89 16.37 13.59 15.78 45.90 73.50 69.64 39.75 33.21 40.70 73.26 78.86 99.12 126.65 153.24 147.16 158.82 163.54 163.61 179.55 189.19 183.19 168.37 158.81 179.73 191.53 168.35 196.33 208.98 220.81 209.83 158.68 143.08
All gas from the Ngatoro field was flared from March 1992 to May 1998. The Ngatoro field includes the Goldie well. All gas from the Rimu field was flared from 1999 to 2001.
101
Energy Data File July 2005
E.3 Gas Production (PJ) Chart E.3a: Quarterly Gas Production
Chart E.3b: Gas Production Percentages (March Years)
2005
102
2004
Section E: Gas
Energy Data File July 2005
Table E.3: Gas Production (PJ) Calendar Year or Month
Total Gross Natural Gas Production
Gas Reinjected
LPG Extracted
Flared
Production Losses & Own Use
Net Natural Gas Production
Manufactured Gas Production
Total Production*
14.06 15.36 40.22 64.35 59.49 47.14 42.52 56.58 96.76 106.32 133.23 169.24 195.57 189.20 209.45 219.01 217.31 228.31 243.23 237.70 227.84 207.67 243.62 253.43 226.85 253.47 254.17 265.25 248.80 189.66 171.30
0.00 0.00 0.00 0.00 0.00 0.00 5.41 11.08 16.14 18.85 20.01 23.27 19.70 19.63 25.53 29.69 27.90 22.11 25.15 24.79 28.66 19.41 27.67 20.48 21.12 17.74 6.85 3.59 0.50 0.01 0.62
0.11 0.15 0.39 0.55 0.68 1.17 0.85 1.30 1.54 1.74 2.59 4.66 5.44 5.44 5.78 5.74 6.01 7.08 7.69 7.98 8.14 7.61 8.94 9.78 9.54 10.02 10.47 11.54 11.40 9.10 9.13
1.03 1.19 2.29 2.13 0.89 7.76 0.78 0.60 0.47 0.30 1.27 0.76 1.26 1.00 1.50 1.88 2.21 2.45 1.88 1.57 1.85 1.24 2.48 3.97 3.09 1.94 1.64 2.59 1.61 1.08 0.91
2.42 1.90 2.74 4.60 3.99 4.75 4.02 3.75 4.65 4.89 5.25 5.00 4.32 4.07 4.14 3.83 3.59 3.65 4.30 4.41 4.77 4.72 5.43 5.76 5.57 5.56 5.51 5.83 5.67 5.76 6.30
10.50 12.13 34.80 57.08 53.93 33.45 31.45 39.85 73.95 80.53 104.11 135.56 164.85 159.06 172.50 177.88 177.61 193.02 204.21 198.95 184.41 174.68 199.10 213.43 187.53 218.21 229.70 241.70 229.62 173.72 154.34
1.62 1.97 0.00 1.97 1.77 1.70 1.46 1.46 1.31 1.11 0.95 0.70 0.39 0.15 0.11 0.10 0.07 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
12.12 14.10 34.80 59.05 55.69 35.16 32.91 41.31 75.26 81.65 105.06 136.26 165.24 159.21 172.61 177.99 177.68 193.02 204.21 198.95 184.41 174.68 199.10 213.43 187.53 218.21 229.70 241.70 229.62 173.72 154.34
1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2000
Mar Jun Sep Dec
60.21 63.72 67.33 62.92
2.47 1.03 1.07 2.29
2.17 2.63 3.02 2.65
0.32 0.46 0.44 0.42
1.27 1.39 1.38 1.47
53.99 58.20 61.42 56.09
0.00 0.00 0.00 0.00
53.99 58.20 61.42 56.09
2001
Mar Jun Sep Dec
61.40 68.29 74.64 60.92
1.81 0.93 0.45 0.41
2.43 3.12 3.37 2.62
0.65 0.72 0.76 0.47
1.40 1.49 1.60 1.34
55.11 62.04 68.46 56.09
0.00 0.00 0.00 0.00
55.11 62.04 68.46 56.09
2002
Mar Jun Sep Dec
55.84 71.05 65.11 56.81
0.46 0.03 0.00 0.00
2.38 3.21 3.16 2.66
0.42 0.52 0.37 0.30
1.23 1.51 1.51 1.42
51.35 65.78 60.06 52.42
0.00 0.00 0.00 0.00
51.35 65.78 60.06 52.42
2003
Mar Jun Sep Dec
50.10 49.13 53.11 37.33
0.01 0.00 0.00 0.00
1.97 2.39 2.74 2.00
0.33 0.27 0.26 0.22
1.42 1.49 1.50 1.35
46.36 44.99 48.61 33.76
0.00 0.00 0.00 0.00
46.36 44.99 48.61 33.76
2004
Mar Jun Sep Dec
40.86 41.78 45.57 43.08
0.00 0.00 0.28 0.34
1.95 2.40 2.61 2.18
0.23 0.19 0.22 0.27
1.46 1.31 1.81 1.71
37.22 37.87 40.66 38.59
0.00 0.00 0.00 0.00
37.22 37.87 40.66 38.59
2005
Mar
36.07
0.33
1.87
0.20
1.51
32.15
0.00
32.15
Year Mar 2004 180.43 Ended Mar 2005 166.51
0.00 0.96
9.08 9.06
0.98 0.88
5.80 6.34
164.57 149.27
0.00 0.00
164.57 149.27
* Note definition changes since Energy Data File January 1997. Total production includes transmission losses.
1 PJ
G.C.V. ~ 0.904 PJ
Section E: Gas
N.C.V.
(See Fuel Properties Table L.6 for detail.)
103
Energy Data File July 2005
E.4 Gas Demand Chart E.4a: Quarterly Gas Demand
Chart E.4b: Gas Demand Share (March Years)
2005
104
2004
Section E: Gas
Energy Data File July 2005
Table E.4: Gas Demand (PJ) Calendar Year or Month 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
*
Total Production
Transmission Losses*
Direct Sales
Reticulated Sales**
Stock Change
12.12 14.10 34.80 59.05 55.69 35.16 32.91 41.31 75.26 81.65 105.06 136.26 165.24 159.21 172.61 177.99 177.68 193.02 204.21 198.95 184.41 174.68 199.10 213.43 187.53 218.21 229.70 241.70 229.62 173.72 154.34
0.53 0.99 0.93 -0.31 -1.06 -0.46 0.53 0.49 0.44 0.50 0.04 2.05 -1.29 -1.63 -0.75 -1.74 -1.38 -1.36 -1.23 0.12 0.17 0.22 0.23 0.28 0.41 0.39 0.54 0.60 0.61 0.80 0.73
2.09 0.24 20.54 44.49 42.38 21.79 15.16 20.12 49.24 49.69 69.47 95.47 123.68 119.00 133.18 139.81 140.20 151.80 164.82 158.87 142.07 132.03 154.02 161.23 131.15 157.00 170.24 177.53 165.15 106.87 90.38
9.49 12.87 13.34 14.87 14.37 13.69 17.06 20.73 25.53 31.46 35.42 38.74 42.58 41.52 39.87 39.66 38.60 42.16 40.32 39.65 41.89 42.18 44.50 51.65 55.93 60.57 58.88 63.11 63.51 65.85 63.12
0.00 0.00 0.00 0.00 0.00 0.14 0.16 -0.03 0.05 -0.01 0.13 0.00 0.27 0.33 0.32 0.25 0.27 0.42 0.31 0.31 0.29 0.25 0.36 0.28 0.04 0.24 0.04 0.45 0.35 0.20 0.10
2000
Mar Jun Sep Dec
53.99 58.20 61.42 56.09
0.13 0.13 0.13 0.13
39.14 43.86 46.06 41.18
14.80 14.13 15.15 14.80
-0.09 0.07 0.08 -0.02
2001
Mar Jun Sep Dec
55.11 62.04 68.46 56.09
0.15 0.15 0.15 0.15
41.12 45.26 50.33 40.83
13.79 16.45 17.82 15.04
0.06 0.18 0.16 0.06
2002
Mar Jun Sep Dec
51.35 65.78 60.06 52.42
0.15 0.15 0.15 0.15
36.12 49.81 43.34 35.89
14.92 15.71 16.49 16.39
0.16 0.12 0.09 -0.01
2003
Mar Jun Sep Dec
46.36 44.99 48.61 33.76
0.20 0.20 0.20 0.20
31.65 28.86 29.69 16.67
14.46 15.83 18.69 16.87
0.05 0.10 0.03 0.02
2004
Mar Jun Sep Dec
37.22 37.87 40.66 38.59
0.18 0.18 0.18 0.18
22.47 21.91 23.22 22.79
14.53 15.78 17.21 15.60
0.04 0.00 0.05 0.01
2005
Mar
32.15
0.18
17.29
14.62
0.06
Year Ended
Mar 2004 Mar 2005
164.57 149.27
0.78 0.73
97.68 85.21
65.92 63.21
0.19 0.12
Estimated.
** Reticulated sales (calculated) include cogeneration. 1 PJ
G.C.V. ~ 0.904 PJ
Section E: Gas
N.C.V.
(See Fuel Properties Table L.6 for detail.)
105
Energy Data File July 2005
E.5 CNG Sales Chart E.5: Quarterly CNG Sales
Table E.5: CNG Sales (PJ) Calendar Year 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
PJ/Year 1.103 2.568 4.010 5.850 5.650 4.973 4.167 3,257 2,650 2.662 2.461 2.275 1.834 1.423 1.056 0.756 0.508 0.037 0.073 0.143 0.191 0.245 0.216
PJ/Quarter 2000
Mar Jun Sep Dec
0.015 0.025 0.020 0.013
2002 Mar Jun Sep Dec
0.033 0.052 0.060 0.046
2004 Mar Jun Sep Dec
0.043 0.064 0.067 0.042
2001
Mar Jun Sep Dec
0.012 0.046 0.050 0.035
2003 Mar Jun Sep Dec
0.054 0.067 0.075 0.049
2005 Mar
0.047
Year Mar 2004 0.234 Ended Mar 2005 0.220
* Estimated from July 2000 to March 2005.
106
Section E: Gas
Energy Data File July 2005
E.6: Gas Consumption and Prices by Sectors
In this section, quarterly gas consumption, gas sales revenue and gas customer numbers reported by the gas retailers for the five calendar years (2000 to 2004) are used to derive average unit prices ($/GJ) and average consumption (GJ). This is summarised along with total consumption for the three main sectors: residential, commercial and industrial. The statistical information which is summarised for the five year period are from the following gas retailers: 1) Contact Energy (2000–2004); 2) Genesis Energy (2002–2004); 3) Natural Gas Corporation (2000–2004); 4) Nova Gas (2000–2004) and 5) Wanganui Gas (2000–2004). NGC ceased gas retailing to the residential sector in December 2002 and Nova Gas has only commercial and industrial customers. The information for a smaller retailer serving mainly commercial customers in Auckland accounting for a few PJ is not part of this statistical collection. During 2004 calendar year, the industrial sector (including for electricity generation and petrochemical production) accounted for 90 percent of the gas consumption share while the commercial sector and the residential sector had only a 6 and 4 percent share, respectively. The residential sector however, was responsible for 95 percent (or about 220,000) of the consumers while the industrial sector comprised about 1% (1,700) and the commercial sector about 4% (9,000) of the consumers (Charts E.6a and E.6b). Over the 2000 to 2004 period, the number of residential consumers rose from about 190,000 to 220,000 with average consumption declining from about 38 GJ to about 31 GJ and the average unit prices, including GST, rising from about $19 per GJ to about $26 per GJ (Table E.6 and Chart E.7). During the same period, the number of commercial consumers declined from
Chart E.6a: Share of Consumption by Sector during 2004
about 13,000 to 9,000 with consumption averaging about 1,000 GJ to 1,200 GJ and average prices, excluding GST, increased from about $8.50 per GJ to about $9.20 per GJ (Table E.7 and Chart E.8). The number of industrial consumers rose from under 1,000 to about 1,700 during the 2000 to 2004 period when the average consumption declined from about 260,000 GJ to 80,000 GJ and the average unit prices, excluding GST, rose from about $3.00 per GJ to about $4.50 per GJ (Table E.8 and Chart E.9). More detailed breakdown of gas consumption by key sub-sectors (according to ANZSIC codes) during 2002 to 2004 indicates that total consumption by the petroleum and chemical products sectors (ie, ANZSIC code C25) declined from 97 PJ in 2002 to about 51 PJ in 2004 while average unit prices rose from $2.60 to $2.90 per GJ and total consumption by the electricity (generation), gas and water sectors (ie, ANZSIC code D) also declined from about 91 PJ in 2002 to about 60 PJ in 2004 when average unit prices for this sector rose from about $3.90 per GJ to over $5.20 per GJ in 2004 (Table E.10). Total gas consumption by all sectors declined from about 230 PJ in 2000 to about 150 PJ in 2004 after rising to about 245 PJ in 2001 while total gas consumer numbers rose from about 200,000 in 2000 to about 230,000 in the 2004 calendar year. Average unit prices across all three sectors rose from about $4.00 per GJ to $5.70 per GJ when average annual consumption halved from about 1,200 GJ to about 660 GJ mainly due to declining industrial sector consumption (Table E.9 and Chart E.10).
Chart E.6b: Share of Consumers by Sector during 2004
Residential 4%
Commercial 4% Industrial 1%
Commercial 6%
Industrial 90%
Section E: Gas
Residential 95%
107
Energy Data File July 2005
Table E.6: Gas Consumption by the Residential Sector Residential Calendar Year or Quarter 2000 2001 2002 2003 2004
Consumption GJ (000)
Sales $(000)
Average Price (incl. GST) $/GJ
Number of Consumers
Average Consumption GJ
7,172 7,207 6,786 6,870 6,707
135,591 136,246 118,672 161,396 171,318
18.91 18.90 17.49 23.49 25.54
187,117 175,172 199,013 211,478 219,367
38.33 41.14 34.10 32.49 30.57
2000
Mar Jun Sep Dec
1,316 1,419 2,461 1,976
24,497 27,240 44,281 39,572
18.62 19.20 17.99 20.03
205,990 185,815 182,020 174,643
6.39 7.64 13.52 11.31
2001
Mar Jun Sep Dec
1,586 1,294 2,503 1,824
31,632 25,600 45,619 33,394
19.94 19.78 18.23 18.31
172,824 173,697 181,124 173,043
9.18 7.45 13.82 10.54
2002
Mar Jun Sep Dec
1,516 1,569 2,004 1,697
29,838 29,869 37,473 21,492
19.68 19.04 18.70 12.66
173,714 203,167 208,485 210,684
8.73 7.72 9.61 8.05
2003
Mar Jun Sep Dec
1,300 1,499 2,877 1,194
32,277 48,920 51,712 28,486
24.83 32.63 17.97 23.86
211,248 209,346 209,731 215,585
6.15 7.16 13.72 5.54
2004
Mar Jun Sep Dec
817 1,727 2,704 1,459
26,307 40,613 60,046 44,353
32.20 23.52 22.21 30.40
216,319 215,138 220,078 225,933
3.78 8.03 12.29 6.46
6,870 6,707
161,396 171,318
23.49 25.54
211,478 219,367
32.49 30.57
Year Dec 2003 Ended Dec 2004
Chart E.7: Average Residential Gas Price1 and Average Consumption
Note: 1
Including GST.
108
Section E: Gas
Energy Data File July 2005
Table E.7: Gas Consumption by the Commercial Sector Commercial Calendar Year or Quarter 2000 2001 2002 2003 2004
Consumption GJ (000)
Sales $(000)
Average Price (excl.GST) $/GJ
Number of Consumers
Average Consumption GJ
14,458 13,705 13,491 9,917 9,226
123,133 114,314 119,209 96,402 84,743
8.52 8.34 8.84 9.72 9.19
12,361 11,228 11,072 10,428 8,990
1,170 1,220 1,218 951 1,026
2000
Mar Jun Sep Dec
3,489 3,681 4,227 3,061
29,702 31,050 34,392 27,989
8.51 8.44 8.14 9.14
13,527 12,265 12,500 11,151
258 300 338 275
2001
Mar Jun Sep Dec
2,551 4,209 4,132 2,813
21,766 33,250 34,655 24,643
8.53 7.90 8.39 8.76
11,440 11,480 11,524 10,468
223 367 359 269
2002
Mar Jun Sep Dec
2,359 4,278 3,888 2,966
21,915 35,163 33,962 28,169
9.29 8.22 8.74 9.50
9,917 11,522 11,375 11,474
238 371 342 259
2003
Mar Jun Sep Dec
1,667 2,456 3,651 2,143
18,196 25,636 32,524 20,046
10.92 10.44 8.91 9.35
10,652 10,453 10,355 10,250
156 235 353 209
2004
Mar Jun Sep Dec
1,849 2,501 2,884 1,992
16,493 20,694 26,917 20,639
8.92 8.27 9.33 10.36
8,968 9,296 8,981 8,714
206 269 321 229
9,917 9,226
96,402 84,743
9.72 9.19
10,428 8,990
951 1,026
Year Dec 2003 Ended Dec 2004
Chart E.8: Average Commercial1 Gas Price2 and Average Consumption
Notes:
1 Includes transport and cogeneration.
2 Excludes GST.
Section E: Gas
109
Energy Data File July 2005
Table E.8: Gas Consumption by the Industrial Sector Industrial Calendar Year or Quarter 2000 2001 2002 2003 2004
Consumption GJ (000)
Sales $(000)
Average Price (excl. GST) $/GJ
Number of Consumers
Average Consumption GJ
210,027 223,349 207,616 157,161 136,514
660,554 761,976 698,428 688,891 613,569
3.15 3.41 3.36 4.38 4.49
903 851 996 1,369 1,702
232,524 262,378 208,502 114,842 80,220
2000
Mar Jun Sep Dec
48,944 52,621 54,584 53,879
166,815 162,551 162,292 168,895
3.41 3.09 2.97 3.13
1,003 902 858 850
48,797 58,338 63,618 63,387
2001
Mar Jun Sep Dec
53,512 57,726 60,211 51,900
170,011 200,979 205,537 185,448
3.18 3.48 3.41 3.57
797 982 1,050 576
67,142 58,785 57,344 90,104
2002
Mar Jun Sep Dec
46,018 60,128 53,852 47,618
169,088 187,128 183,516 158,695
3.67 3.11 3.41 3.33
854 1,228 1,132 769
53,885 48,964 47,572 61,922
2003
Mar Jun Sep Dec
43,255 40,074 44,047 29,785
176,802 192,314 198,134 121,641
4.09 4.80 4.50 4.08
1,424 1,364 1,356 1,330
30,376 29,380 32,484 22,395
2004
Mar Jun Sep Dec
34,535 32,986 34,642 34,351
140,503 144,367 162,074 166,625
4.07 4.38 4.68 4.85
1,697 1,731 1,708 1,671
20,350 19,056 20,282 20,557
157,161 136,514
688,891 613,569
4.38 4.49
1,369 1,702
114,842 80,219
Year Dec 2003 Ended Dec 2004
Chart E.9: Average Industrial1 Gas Price and Average Consumption
Note: 1
Excludes GST.
110
Section E: Gas
Energy Data File July 2005
Table E.9: Gas Consumption by All Sectors All Sectors Calendar Year or Quarter 2000 2001 2002 2003 2004
Consumption GJ (000)
Sales $(000)
231,657 244,261 227,893 173,948 152,447
919,278 1,012,535 936,309 946,689 869,630
Number of Consumers
Average Consumption GJ
3.97 4.15 4.11 5.44 5.70
200,381 187,251 211,080 223,274 230,059
1,156 1,304 1,080 779 663
Average Price 1 $/GJ
2000
Mar Jun Sep Dec
53,749 57,721 61,272 58,916
221,014 220,841 240,965 236,457
4.11 3.83 3.93 4.01
220,520 198,982 195,378 186,644
244 290 314 316
2001
Mar Jun Sep Dec
57,649 63,229 66,846 56,537
223,409 259,829 285,812 243,485
3.88 4.11 4.28 4.31
185,061 186,159 193,698 184,087
312 340 345 307
2002
Mar Jun Sep Dec
49,893 65,975 59,744 52,281
220,841 252,159 254,951 208,357
4.43 3.82 4.27 3.99
184,485 215,917 220,992 222,927
270 306 270 235
2003
Mar Jun Sep Dec
46,222 44,029 50,575 33,122
227,275 266,870 282,371 170,173
4.92 6.06 5.58 5.14
223,324 221,163 221,442 227,165
207 199 228 146
2004
Mar Jun Sep Dec
37,201 37,214 40,230 37,802
183,303 205,673 249,037 231,617
4.93 5.53 6.19 6.13
226,984 226,165 230,767 236,318
164 165 174 160
173,948 152,447
946,689 869,630
5.44 5.70
223,274 230,059
779 663
Year Dec 2003 Ended Dec 2004
Chart E.10: Annual Gas Consumption by Sector
1
Natural gas prices for ‘all sectors’ are weighted average prices calculated for each quarter, based on information provided by the retailers of natural gas. The average prices include GST for the residential sector and exclude GST for the commercial and industrial sectors.
Section E: Gas
111
112
Table E.10: Gas End Use for 2002, 2003 and 2004 2002 ANZSIC
Consumption GJ (000)
INDUSTRIAL2 ....................................
Average Price 1 $/GJ
2003
No. of Average Consumers Consumption GJ
Consumption GJ (000)
Average Price 1 $/GJ
2004
No. of Average Consumption Consumers Consumption GJ GJ (000)
Average Price 1 $/GJ
No. of Consumers
Average Consumption GJ
80,220
207,616
3.4
996
208,502
157,161
4.4
1,369
114,779
136,514
4.5
1,702
Agriculture, forestry and fishing
A
799
6.5
146
5,473
1,341
6.7
82
16,354
1,628
7.1
192
8,490
Mining
B
134
4.7
5
29,778
168
5.6
8
22,400
191
5.8
9
22,471
Food, textile, footwear and leather
C21–C22
8,990
4.9
270
33,265
12,568
5.7
292
43,041
10,491
6.1
415
25,295
Wood & paper products, printing & publishing
C23–C24
8,521
3.9
115
74,096
8,122
4.9
93
87,569
8,912
5.6
154
57,776
C25
96,675
2.6
75
1,284,718
46,522
3.2
72
650,657
51,434
2.9
81
638,928
Petroleum, coal and chemical products 3
C26–C29
1,262
6.1
298
4,238
2,106
6.8
464
4,541
3,329
6.8
431
7,728
Electricity, gas and water
D
91,201
3.9
36
2,515,890
86,238
4.7
314
274,862
60,387
5.2
282
214,328
Construction
E
34
9.0
51
670
96
10.5
46
2,087
142
7.6
140
1,018
13,491
8.8
11,072
1,218
9,917
9.7
10,428
951
9,226
9.2
8,990
1,026
10,786
9.3
8,641
1,248
3,732
12.7
8,535
437
2,740
9.9
4,543
603
I
191
7.6
58
3,322
245
7.9
50
4,876
216
8.7
118
1,834
COMMERCIAL ................................ 4
Wholesale and retail trade Transport and storage Communication services
F, G, H J, K, L
201
9.7
314
640
350
13.4
314
1,116
464
12.7
721
644
Government (including foreign), administration and defence
M
292
7.4
172
1,703
432
9.8
180
2,407
508
10.0
280
1,813
Education, cultural, recreational and personal services
N, P, Q
915
9.2
1,656
553
3,794
7.1
1,030
3,683
3,710
8.4
2,576
1,440
Health and community services
O
1,106
4.6
232
4,772
1,364
8.2
319
4,279
1,588
8.4
753
2,110
NON-RESIDENTIAL ..........................
221,107
3.7
12,068
18,322
167,078
4.7
11,797
14,163
145,740
4.8
10,692
13,631
RESIDENTIAL ....................................
6,786
17.5
199,013
34
6,870
23.5
211,478
32
6,707
25.5
219,367
31
TOTAL SALES ................................
227,893
4.1
211,080
1,080
173,948
5.4
223,274
779
152,447
5.7
230,059
663
5
Notes: 1 2
Section E: Gas
3
4 5
Residential average prices include GST, while industrial and commercial average prices do not include GST. Industrial figures provided here do not agree with the industrial figures in the energy balance tables (Section B). The industrial figures in the energy balance tables are calculated by the reticulated sales less gas consumed by the residential, commercial and transport sectors. The ANZSIC category C25 includes non-energy uses (natural gas used as feedstock for the production of methanol and ammonia/urea), as well as energy sources for petroleum refining and the production of petroleum and coal products, fertiliser, industrial gases and synthetic resin, organic industrial chemicals and inorganic industrial chemicals. Includes transport and cogeneration. Total market natural gas prices are a weighted average price, based on information provided by the retailers of natural gas.
Energy Data File July 2005
Metal, non-metallic, machinery products and other manufacturing
Energy Data File July 2005
This page is left intentionally blank.
Section E: Gas
113
E. Gas Figure E.1: Gas Flows for March Year 20051 By gross production:
FIELDS By net production:
5.1%
4.5%
63.7%
16.7%
0.6%
McKee
Mangahew a
Mau i
Kapuni
Ngatoro 2
4.9%
65.8%
15.1%
0.1%
5.4%
Todd Taranaki 100%
PRODUCERS Operator: Todd Taranaki
Shell Explo 38.75% EPIL 20.00% Shel l (Petro ) 18.75% OMV 10.00% Todd Energy 6.25% TOPC 6.25%
Shel l (Petro ) 50% Todd Energy 50%
Operator: Shel l Todd Oil Servi ces
Operator: Shel l Todd Oil Servi ces
WHOLESALER
The Crown
0.2%
Greymouth 87% Southern 9% Greymouth Petro 4%
Operator: Greym outh Pe tro
EGCL
Ngatoro Gas Storage Pro j ect
EFNZL
6.1%
3.1%
Kaimi ro
TAWN
Rimu 3
0.1%
5.5%
3.1%
Greymouth 100%
Southern Petro 96.76% Sw i ft Energy 3.24%
Sw ift Energy 100%
Operator: Sw ift Energy
Operator: Sw ift Energy
Operator: Greym outh Petro
Contact Energy
Genesis Pow er
NGC
TRANSMITTERS (high press ure)
DISTRIBUTORS (low pressure)
RETAILERS
Pow erco, Vector Genesis Energy4
NGC, Nova Gas, W anganui Gas, Others5
Contact Energy
Major users supplied directl y from the transm i ssion system
CONSUMERS
By consumpti on: (c alc ulated)
Users supplied from distributi on systems
New Zealand Steel Carter Ho l t Harvey Degussa Perox i de Fonterra Co-operati ve Todd Energy/ Kiw i Cogeneration NZ Re fi nery Company Southdown Cogeneration Tasman Pulp and Paper and som e other com pan i es
Methanex Ot her indus t ry , commerc ial, res idential, t ransport (as CNG )
42.9%
Chemical methanol manufacture
24.4%
Ball ance AgriNutri ents (Kapun i) Lim i ted
Contact Energy Genesi s Power
Ammonia/urea manufacture
Electric ity generation
4.9%
27.8%
The arrows portray significant flows of gas ownership up to the wholesale/transmission stage. They portray the physical and/or ownership flow of gas from the distribution stage onwards. Company names are listed without the suffixes “Limited” and “New Zealand Limited” where applicable. EFNZL is Energy Finance New Zealand Limited, EGCL is Energy Gas Contracts Limited, EPIL is Energy Petroleum Investments Limited (owned by Shell Investments NZ Limited), Greymouth is Greymouth Petroleum Acquisition Company Ltd, Greymouth Petro is Greymouth Petroleum Limited, KGCL is Kapuni Gas Contracts Limited, NGC is NGC New Zealand Limited, OMV is OMV New Zealand Limited, Shell Explo is Shell Exploration NZ Limited, Shell (Petro) is Shell (Petroleum Mining) Company Limited, Southern is Southern Petroleum (Ohanga) Limited, Southern Petro is Southern Petroleum (New Zealand) Exploration Limited, Swift Energy is Swift Energy New Zealand Limited, TAWN is Tariki, Ahuroa, Waihapa and Ngaere, Todd Energy is Todd Petroleum Mining Company Limited, Todd Taranaki is Todd Taranaki Limited, TOPC is Taranaki Offshore Petroleum Company of New Zealand (owned by Shell Oil Company of the United States). Net production is calculated as gross production less reinjected, flaring, own use, losses and LPG extracted. Notes: 1 Ownership as at 31 March 2005 and excludes LPG. 2 Includes Goldie well. 3 Includes Kauri well. 4 From October 2004, Genesis Energy (retailer) has delivered gas to major users supplied directly from the transmission system. 5 Others include Mercury Energy, Bay of Plenty Electricity, E Gas and Auckland Gas Company.
90
Section E: Gas
Energy Data File July 2005
Overview of New Zealand’s Gas Industry
All statistics in this commentary apply to the year ended March 2005, and comparisons apply to that year relative to the year ended March 2004, unless otherwise specified. Overall comments are related to actual and proposed developments in the gas industry as at July 2005.
Ownership Reform of the gas industry began in 1987 when the Crown publicly floated 30% of Petrocorp, through which the Government had managed its interests in the production, transmission and distribution of gas. The Government’s remaining interest in Petrocorp, including the Natural Gas Corporation Limited (NGC), was sold in 1988. The Australian Gas Light Company (AGL) became a majority owner (66.05%) of NGC after it bought Fletcher Challenge Energy (FCE)’s share. In October 2004, AGL sold its 66.05% interest in the North Island’s major gas pipeline company, NGC Holdings Ltd, to Auckland-based energy networks company Vector Limited. In July 2004, Australian company Origin Energy bought a 51.2% stake in Wellington-based Contact Energy from Californian-based Edison Mission Energy. Two petroleum mining permits (PMPs) were granted by Crown Minerals during 2004 and two PMPs have been granted during the first half of 2005. There are now 16 petroleum mining (production) permits in New Zealand. On 8 October 2004, a 155.8 sq-km offshore permit was granted over the Pohokura field. The field operator, Shell Todd Oil Services, has indicated (June 2004) mean hydrocarbon reserves of 700 Bcf gas and 42.8 mmbbls of condensate. Pohokura joint venture partners are Shell Exploration NZ Ltd (48.00030%), OMV NZ Ltd (25.99985%) and Todd Pohokura Ltd (25.99985%). This reflects changes to the permit endorsement effective from 7 July 2005. In September 2004, a 5.99 sq-km onshore PMP for the production of gas and condensate was granted over the Kahili field in the Taranaki Basin. The Kahili joint venture partners are Austral Pacific Energy Ltd (20% and operator), Tap New Zealand Pty Ltd (30%), International Resource Management Corporation (25%) and Millennium Oil and Gas Ltd (25%). In April 2005 a 35.24 sq-km petroleum mining permit, straddling both onshore and offshore areas in the south Taranaki region, was granted for the production of oil and gas from the Kauri field. This permit lies immediately to the south of the existing Rimu PMP (granted in early 2002). Swift Energy New Zealand Limited is the permit operator and holds 100% of the permit equity. PMP documents indicate reserves of up Section E: Gas
to 233 Bcf of gas and 15 mmbbls of oil. In May 2005 a 22.48 sq-km PMP was granted over the Radnor field in the onshore Taranaki basin. The Radnor joint venture partners are Bridge Petroleum (66.67% and operator) and Westech Energy New Zealand (33.33%). Permit documents indicate proven plus probable reserves of 20 Bcf and 0.8 mmbbls. This permit was granted as a result of good flow rates obtained from the Radnor-1 well drilled in the third quarter of 2004. (Source: Various issues of New Zealand Petroleum News – Ministry of Economic Development).
Exploration and Development The 18-month period from 1 January 2004 through to 30 June 2005 saw a substantial increase in gas exploration and development activities. During 2004 a total of 32 wells were drilled (including side tracks and a well abandoned at shallow depth). A total of approximately 73,800 m were made in oil and gas wells, a large increase on the 2003 figure of approximately 35,200 m from 16 wells. Of the 32 wells drilled in 2004, 15 were exploration wells, and 17 were appraisal or development wells. Discoveries were made on two of the exploration wells, indicating a 13% success rate. Figures for the first half of 2005 show that 13 wells (including side tracks) were spudded and it is anticipated that no fewer than eight wells will be drilled in the second half of 2005, bringing the total to at least 21. A majority of wells drilled and planned for 2005 are either appraisal or development wells, although exploration activity remains buoyant. Highlights of drilling campaigns conducted during 2004 and the first half of 2005 included the offshore programme in petroleum exploration permit (PEP) 38460, and subsequent application for a PMP by the joint venture, the large drilling programme completed by Swift Energy in PEP 38719 and the subsequent award of a PMP over the Kauri field, good results from drilling in PEP 38738 (Cheal and Cardiff) and the successful results of the Radnor-1 well (Bridge Petroleum, PEP 38752), which was subsequently granted a PMP in May 2005. Coupled with this increase in drilling activity is an increase in the number and type of seismic acquisition surveys conducted throughout the same 18-month period. A large 3D seismic acquisition vessel was mobilised to New Zealand waters early in the first quarter of 2005 and conducted a multi-permit programme. The third largest onshore 3D seismic survey was conducted by Todd Exploration Limited during the first half of 2005. More 3D seismic data have been acquired during the first half of 2005 than in any other year to date. Substantial development activities during 2004 in91
Energy Data File July 2005
cluded the granting of the Pohokura mining permit and progress on development plans for the Kupe oil and gas field. The drilling of extended reach production wells (from an onshore location) in the Pohokura field commenced during the second quarter of 2005, using the largest onshore rig ever mobilised to New Zealand. The drilling of offshore production wells is scheduled to commence in early 2006. Initial production is expected to be 50 PJ of gas and 3 mmbbls of condensate per annum commencing in late 2006. The Pohokura development is the second offshore hydrocarbon production project to be initiated in New Zealand and the Pohokura platform will be New Zealand’s third offshore production facility, after the Maui A platform (first production in 1979) and the Maui B platform (commissioned in 1992). Australian-based Origin Energy has outlined its proposed developments for the Kupe oil and gas field. Kupe is expected to produce 20 PJ of gas and 1.6 mmbbls of oil per annum when it comes on-stream. Production from the Kupe field is expected to commence in the second quarter of 2007. As part of the industry-led initiative to develop an open access regime for the Maui gas transmission pipeline owned by Maui Development Limited (Shell New Zealand, OMV New Zealand and Todd Energy), an agreement was reached with NGC for the development of an “open access” operating system. Under the agreement, NGC will use a single information platform to operate open access arrangements for both the NGC pipeline system and the 313 km onshore Maui pipeline from the Maui production station in south Taranaki to Huntly power station, south of Auckland. In August 2004, Genesis Energy committed to proceed with the construction of a new gas-fired powerstation. The facility, called e3p (e3p stands for Huntly Energy Efficiency Enhancement Project), is located at Huntly, and is the first major power generation plant using gas to be built for five years. Genesis has entered into longterm contracts for the supply of Kupe, Mangahewa, McKee and Pohokura gas. The $520 million project is one of the largest infrastructure projects currently underway in New Zealand. NGC Holdings Ltd expanded the output at its Kapuni gas treatment plant by almost 55% in the last financial year. In the past year the Kapuni gas treatment plant has been upgraded primarily to process greater quantities of Kapuni gas for the retail market, as well as to receive gas from other sources. As a result of these projects the Kapuni plant will supply an additional 8 PJ of treated gas a year, taking the annual treated gas output to over 22 PJ. LPG production will increase from 35,000 to 40,000 tonnes a year due to improved yields and there has been the addition of a 100-tonne storage vessel. (Source: Various issues of New Zealand Petroleum 92
News – Ministry of Economic Development).
The Government’s package of measures to encourage gas exploration In June 2004, the Government announced a package of measures to encourage gas exploration and development in New Zealand. These were incorporated in the Minerals Programme for Petroleum 2005 which came into effect on 1 January 2005. Amongst the changes introduced by the new Programme are: Royalties 1. Ad Valorem Royalties (AVR) on “discoveries” made between 30 June 2004 and 31 December 2009 (“the period”) as follows: – 1% for gas (was 5%); – 5% for oil (unchanged). 2. Accounting Profit Royalty (APR) of 15% for the first $750,000,000 of gross sales (offshore) for discoveries made during the period (was 20%). 3. APR of 15% for the first $250,000,000 of gross sales (onshore) for discoveries made during the period (was 20%). 4. “Ring Fencing” – all prospecting and exploration costs incurred anywhere in New Zealand (in any permit) during the period will be deductible for the purpose of calculating the APR on a mining permit granted for depleting a discovery made during the period. Costs incurred during the period and prior to the granting of a petroleum mining permit will be allowed to be carried forward for deduction with annual interest at the 10-year Government bond rate +1%. 5. Production from fields that do not qualify as a “Discovery” will pay royalties as per the 1995 Minerals Programme. Other initiatives to promote exploration in New Zealand included the securing of Government backing for a $15 million seismic data acquisition project. A 2D seismic acquisition survey over the central and northern parts of the East Coast Basin (designated Crown Minerals – CM-05) commenced on 26 February and was completed on 13 April 2005. A total of approximately 3,000 km of data was acquired. This basin is under-explored, with only three offshore wells drilled. The CM-05 survey has significantly increased understanding of the oil and gas potential of the East Coast Basin. The data acquired, and the results of subsequent geotechnical studies (conducted by the Institute of Geological and Nuclear Sciences – IGNS), will be released to industry free of charge to encourage further exploration in those areas. Concurrent with these activities, rights to a spec survey shot in 2001 over the Outer Taranaki Basin have been negotiated (6,440 km of 2D seismic data acquired by TGS Nopec and interpretation report by IGNS). The duration of the Northland Blocks Offer was extended Section E: Gas
Energy Data File July 2005
following the successful negotiation of the purchase of approximately 9,000 km of reprocessed 2D seismic data and an accompanying seismic interpretation report (completed by IGNS). Both of these data sets were distributed to interested parties during the second quarter of 2005 in order to support the Outer Taranaki Blocks Offer and the Northland Blocks Offer.
Taxation The so called “183 day rule” was amended during 2004 to the effect that offshore exploration rigs and seismic acquisition ships may work in New Zealand waters for a period of 365 days before operators are liable to pay resident withholding tax.
Kaimiro, owned by Greymouth Petroleum Acquisition Company Limited. Together they provide the remaining 20% of total gas production. (See Chart E.1a.) Figure E.1 presents a schematic of natural gas ownership and physical flows in New Zealand for the March year 2005, with proportions of gas produced by the different fields and consumed by major user/supplier categories. Chart E.1a: Gross Gas Production by Field
Deregulation The gas (and electricity) industries were deregulated in 1993 with the removal of gas franchise areas and the lapsing of wholesale gas price controls (retail price control had already lapsed). In October 2004, the Electricity and Gas Industries Bill, which amends the Gas Act 1992, was passed. The amendments provide for the establishment of an industry body. This body will make recommendations to the Minister on the instigation of arrangements, including rules and regulations for wholesaling, processing, transmission and retailing matters. The Government’s objectives for the gas industry are articulated in the draft Government Policy Statement (GPS) on Gas Governance which was released in October 2004. The Gas Industry Company (GIC) was approved as the industry body in December 2004. The GIC is currently developing its systems and processes to meet the Government’s objectives as outlined in the GPS on Gas Governance.
Production Currently, gas is produced entirely in the Taranaki region, where 11 fields produce gas. New Zealand’s production of natural gas has been dominated by the Maui field. The Maui field and the Kapuni field are owned by Shell Petroleum Mining and Todd Energy. These two fields together provide 80% of total production. They are both operated by Shell Todd Oil Services Limited. Other fields in production during the year to March 2005 were McKee and Mangahewa (from September 2001), owned by Todd Taranaki Limited; the Waihapa/Ngaere and Tariki/Ahuroa fields, owned by Southern Petroleum New Zealand Exploration Limited and Swift Energy New Zealand Limited; Rimu (including Kauri well) owned by Swift Energy New Zealand Limited; Ngatoro (including the Goldie well, which recommenced production in December 2003), owned by Greymouth Petroleum Acquisition Company Limited, Southern Petroleum (Ohange) Limited and Greymouth Petroleum Limited; and Section E: Gas
* Includes the Goldie well. ** Others include Mangahewa and Rimu fields.
As Chart E.1a illustrates, the Maui field was the major source of gas production, providing 63.7% of New Zealand’s gross gas production in the year ended March 2005. The Kapuni field produced 16.7%, Tariki/ Ahuroa 6.0%, Mangahewa 4.5%, McKee 5.1%, Rimu (including Kauri well) 3.1%, Ngatoro (including Goldie well) 0.6%, Kaimiro 0.2%, and Waihapa/Ngaere 0.1% of total gas production. Total New Zealand gas production in the year ended March 2005, excluding gas reinjected or flared and LPG extracted, was 155.6 PJ, a decline of 8.7% compared with 170.4 PJ in the year ended March 2004. This was due to decreases in production at Tariki/ Ahuroa (32%) and Kaimiro (32%), Mangahewa (14%), Waihapa/Ngaere (12%), Maui (11%), and Kapuni (0.1%). There was no gas reinjected for the March year 2004, but there was some (1.0 PJ) for the March year 2005. The Rimu, Ngatoro (including Goldie well) and McKee fields increased their production by 113%, 68% and 18% respectively, compared with the year ended March 2004.
Distribution There are over 3,400 km of high-pressure gas transmission pipelines in New Zealand. The major gas transmission pipelines are NGC’s network and the Maui pipeline, which is owned by Maui Development Limited. Other transmission pipelines are owned by Todd Petroleum and Shell, Todd Taranaki, Swift Energy and Westech Energy. More than 2,800 km of intermediate, medium and low pressure gas distribution pipeline networks in the North Island are connected to the high pressure 93
Energy Data File July 2005
transmission system. NGC also operates extensive gas distribution and retail operations in the North Island of New Zealand. There are five gas distributors: NGC Infrastructure, Nova Gas, Wanganui Gas, Vector and Powerco, and nine retailers: NGC, Nova Gas, Wanganui Gas, Contact Energy (gas wholesaler/retailer), Genesis Energy, Mercury Energy, Bay of Plenty Electricity, E Gas and Auckland Gas Company.
Liquefied petroleum gas In addition to natural gas, the gas industry produced 9.4 PJ of liquefied petroleum gas (LPG) in the year ended March 2005, 8.1% higher than the year ended March 2004 level of 8.7 PJ. Of the 9.4 PJ of production, 0.8 PJ was exported and 8.1 PJ was used in New Zealand. In the year ended March 2005, 0.4 PJ of LPG was imported into New Zealand. LPG statistics are included in the Oil section and are presented in Section D.14.
Compressed natural gas CNG is supplied to the automotive market through North Island service stations. The CNG market has decreased markedly since the removal of government subsidies in 1987. Estimated CNG sales are presented in Section E.5.
End use The three major groups of users of gas in New Zealand are petrochemicals, electricity generation and direct reticulated users, as Chart E.1b (below) illustrates.
Chart E.1b: Gas Use by Sector (March Years)
Petrochemicals The petrochemicals sector used around 29% of New Zealand’s natural gas during the year ended March 2005 (in Methanex’s methanol plants at Motunui and Waitara, and the Ballance Agri-Nutrients (Kapuni) ammonia/urea plant) compared with 26% in the year ended March 2004. Crude methanol is produced from natural gas and then distilled into high (“AA”) grade methanol. Methanex New Zealand produced 120,000 tonnes of methanol during the first quarter 2005 compared with 260,000 tonnes of methanol during the fourth quarter 2004. The reduction of methanol production was due to the closure of Motunui plant as a consequence of natural gas supply constraints. Ballance Agri-Nutrients (Kapuni) Limited (previously Petrochem Limited) manufactures ammonia/urea from natural gas. The ammonia/urea plant uses Maui gas for fuel and a mixture of Maui and Kapuni LTS gas as feedstock.
Electricity generation Gas used for electricity generation (including cogeneration) was about 41% of New Zealand’s natural gas produced during the year ended March 2005. Of the 41% of gas used for generation, 28% was used for electricity generation and 13% was used for cogeneration. Contact Energy Limited (Otahuhu B, Taranaki Combined Cycle and New Plymouth) and Genesis Power Limited (Huntly) are the main thermal electricity generators in New Zealand using natural gas. Gas consumption for electricity generation and cogeneration decreased by 24% and 25% to 41 PJ and 19 PJ respectively, in the year ended March 2005, compared with the year ended March 2004 levels of 55 PJ and 25 PJ respectively.
Reticulated end use The remaining 30% of New Zealand’s gas use was reticulated throughout the North Island (by NGC) through a highpressure pipeline system direct to major users, and to gas utilities for distribution to other industrial users and to the commercial and residential sectors. Of the 44.4 PJ of consumer energy (excluding cogeneration) reticulated in the year ended March 2005, 28.1 PJ (63.3%) was used by industry, 8.9 PJ (20.1%) by the commercial sector, 7.2 PJ (16.1%) by the residential sector and 0.2 PJ (0.5%) in transport
94
Section E: Gas
Energy Data File July 2005
Chart E.1c: Reticulated End Use by Sector
Chart E.4a shows gas demand by direct major users (petrochemicals and electricity generation) and reticulated end use (industrial, commercial, residential and transport) from the March quarter 1974 to the March quarter 2005 and Chart E.4b compares gas demand share for March years 2004 and 2005. Gas demand by petrochemicals and electricity generation was about 104 PJ, 15% lower than the year ended March 2004 level of 123 PJ and gas demand by reticulated end use (including cogeneration) decreased by 4.1% to 63 PJ.
(as CNG), as Chart E.1c (above) illustrates. Annual per capita end use of gas is 10.9 GJ (298 m3). Reticulated demand (observed, excluding cogeneration) increased 8.4% to 44.4 PJ from 41.0 PJ in the year ended March 2004.
Section E: Gas
Chart E.4b shows that in the year ended March 2005 gas demand by direct and reticulated users was 57% and 43% respectively, compared with 60% and 40% in the year ended March 2004. This was mainly due to a decline in gas consumption by Methanex and electricity generation.
95
96
Figure E.2: Gas Flow Summary for March Year 2005 Petajoules (to approximate vertical scale)
PRODUCTION
CONVEYANCE
USE
Gas reinjected 1.0 LPG extracted 9.1 Gas flared and own use 7.2 Fields
Non-energy use Transmission
Kapuni
Maui Development Limited
Mangahewa
Field operators
Maui
Greymouth Petroleum Limited
McKee Ngatoro Rimu
166.5
New Zealand Oil and Gas Services Limited
1
2
Shell Todd Oil Services Limited
Tariki/Ahuroa Waihapa/Ngaere
Direct supply
Methanex New Zealand Limited Ballance Agri-Nutrients (Kapuni) Limited
Natural Gas Corporation of New Zealand Limited (NGC) 149.2
43.7
Electricity generation Direct supply
Swift Energy New Zealand Limited
41.5
149.2
Contact Energy Limited Genesis Power Limited
Todd Petroleum and Shell
Swift Energy New Zealand Limited
18.8
Todd Taranaki Distribution3 Gas distribution companies
Westech Energy
44.4
Cogenerators
Other Industry Uses
28.1
Commercial
8.9
Residential Gross production
Section E: Gas
Notes:
New Zealand Steel Limited Carter Holt Harvey (Kinleith) Contact Energy (Te Awamutu) Degussa Peroxide Limited Fonterra Co-operative NGC, Kapuni Cogeneration Plant New Zealand Refinery Company Limited Southdown Cogeneration Tasman Pulp and Paper Limited Te Rapa Cogeneration Plant Todd Energy/Kiwi Cogeneration
Net production
Calculated 149.2
Statistical difference 0.8
Observed 148.4
1
Includes the Goldie well.
2
Includes the Kauri well.
3
Gas supplied through distribution systems is used by industry (including cogeneration), the commercial, residential and transport sectors. Some cogenerators and other industrial users are supplied directly.
7.2
Transport 0.2
Energy Data File July 2005
Kaimiro
Energy Data File July 2005
E.1 Gross Gas Production by Field* * Includes gas flared, gas reinjected, LPG extracted, own use and losses
Table E.1a: Gross Gas Production by Field1 (PJ) Calendar Year 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Maui
Kapuni
McKee
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 17.87 23.40 32.83 66.49 71.40 96.48 125.79 153.26 148.91 162.41 167.88 165.98 170.98 183.55 176.64 162.31 152.92 173.53 183.76 156.71 186.76 195.67 203.56 186.63 127.35 111.29
4.31 8.21 11.29 13.31 14.06 15.36 40.22 64.35 59.49 29.27 19.12 23.75 30.28 34.74 35.89 40.08 38.60 36.05 42.55 45.98 44.59 46.25 49.04 48.43 51.50 42.84 52.72 46.12 45.43 42.94 34.88 31.99 28.81 27.21 27.79
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.70 2.43 2.98 3.49 3.73 4.56 4.97 5.58 6.19 6.25 7.74 8.83 9.04 9.53 8.92 10.02 9.36 9.38 5.95 6.83 8.18
Waihapa/ Kaimiro/ Ngaere/Piakau2 Moturoa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.31 5.05 3.95 5.63 5.15 1.97 1.22 0.77 0.60 0.63 0.28 0.30 0.28 0.23 0.26
Notes:
1 For definition of terms used see Glossary, Section K. 2 Piakau has not produced gas since September 1999.
Tariki/ Ahuroa
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.18 0.16 0.93 0.72 0.75 0.77 0.59 0.47 0.45 0.39 0.42 0.72 0.72 1.19 1.45 1.16 1.04 0.61 0.47 0.56 0.46 0.33
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5.33 9.91 9.76 10.54 11.35 13.62 14.26 16.31 10.79 3 4
Mangahewa Ngatoro3 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.60 2.44 0.00 0.00 3.22 9.89 8.41 7.98
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.11 0.33 0.42 0.38 0.59 1.29 1.82 1.53 2.01 2.11 1.60 0.83 0.80
Rimu4
Total
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.60 0.82 2.04 3.88
4.31 8.21 11.29 13.31 14.06 15.36 40.22 64.35 59.49 47.14 42.52 56.58 96.76 106.32 133.23 169.24 195.57 189.20 209.45 219.01 217.31 228.31 243.23 237.70 227.84 207.67 243.62 253.43 226.85 253.47 254.17 265.25 248.80 189.66 171.30
Includes Goldie well.
Includes Kauri well.
Chart E.1a1: Annual Gross Gas Production by Field (PJ)
Notes:
1 Includes Kaimiro, Mangahewa, Ngatoro (including Goldie well), Moturoa and Rimu (including Kauri well) fields.
2 Piakau has not produced gas since September 1999.
Section E: Gas
97
Energy Data File July 2005
Table E.1b: Gross Gas Production by Field1 (Mm3) Calendar Year 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Maui
Kapuni
McKee
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 468.1 628.0 879.5 1,773.5 1,876.6 2,499.2 3,224.4 3,901.0 3,783.1 4,113.9 4,247.1 4,199.8 4,307.9 4,610.8 4,407.4 3,998.8 3,719.2 4,218.4 4,456.6 3,778.4 4,517.7 4,775.0 4,992.9 4,555.7 3,082.5 2,693.7
158.0 301.0 414.0 488.0 515.4 565.9 1,502.0 2,346.8 2,175.2 1,077.2 714.4 889.0 1,156.0 1,300.1 1,326.0 1,468.5 1,413.8 1,334.2 1,567.6 1,714.1 1,666.0 1,740.6 1,862.3 1,826.8 1,958.7 1,622.5 1,978.2 1,703.1 1,681.8 1,593.3 1,303.8 1,204.7 1,079.9 1,010.5 1,034.7
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 16.7 57.6 72.1 83.9 88.5 108.8 119.6 136.6 153.3 154.9 191.6 218.7 224.0 236.2 221.0 243.0 228.8 228.0 144.0 165.8 199.3
Waihapa/ Kaimiro/ Ngaere/Piakau2 Moturoa 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 29.3 112.6 88.1 125.5 114.9 43.9 27.2 17.7 15.2 15.4 6.9 7.3 6.9 5.2 6.6
Notes:
1 For definition of terms used see Glossary, Section K.
2 Piakau has not produced gas since September 1999.
New Zealand’s natural gas production has historically been dominated by the Maui field and still accounted for around 65% of New Zealand’s total gas production in the calendar year 2004. Charts E.1a1 and E.2a show gross and net gas production respectively by field from 1970 to 2004. Gross gas production is total gas production after the first separation point. See Figure H.1. Net gas production is the difference between gross gas production and the amount of gas flared, gas reinjected, LPG extracted, own use and losses.
98
Tariki/ Ahuroa
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 4.7 4.2 24.2 18.7 19.5 20.0 15.3 12.1 11.7 10.1 10.8 18.7 18.6 30.9 37.4 30.1 27.6 17.3 14.8 15.3 12.7 15.7 3 4
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 105.9 194.0 191.2 236.5 254.0 310.9 327.2 338.4 239.2
Mangahewa 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 15.1 60.8 0.0 0.0 83.1 255.5 217.4 205.9
Ngatoro3
Rimu4
Total
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 2.1 6.3 8.1 7.5 11.4 24.9 34.6 29.6 39.0 41.7 31.7 16.1 20.0
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.3 0.3 13.7 16.7 44.1 86.8
158.0 301.0 414.0 488.0 515.4 565.9 1,502.0 2,346.8 2,175.2 1,545.2 1,342.4 1,768.5 2,929.5 3,181.4 3,846.0 4,774.5 5,405.6 5,220.8 5,790.0 6,085.2 6,026.8 6,309.4 6,726.8 6,531.7 6,290.8 5,630.4 6,596.0 6,685.0 6,013.0 6,663.3 6,625.1 6,897.1 6,432.9 4,892.8 4,501.8
Includes Goldie well. Includes Kauri well.
Chart E.2a shows that total New Zealand net gas production fell 11% to 154 PJ in 2004, compared with 174 PJ in the year ended December 2003. Overall, the amount of gas flared, gas reinjected, LPG extracted, own use and losses has generally been increasing since around 1978, decreased by 17% from 2002 to 2003 but increased by 6.4% to 17 PJ between 2003 and 2004. Of the total 17 PJ, 47% or 8 PJ relates to the Maui field, 30% or 5 PJ to the Kapuni field and the remaining 23% to the McKee, Kaimiro, TAWN, Mangahewa, Rimu and Ngatoro (including Goldie well) fields. Net gas production for the Kapuni field from 1970 to 1973 has been estimated, assuming that net production was 95% of gross production.
Section E: Gas
Energy Data File July 2005
Table E.1c: Gross Gas Production by Field1 (Bcf) Calendar Year 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Maui
Kapuni
McKee
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 16.53 22.18 31.06 62.63 66.27 88.26 113.87 137.76 133.60 145.28 149.98 148.32 152.13 162.83 155.65 141.22 131.34 148.97 157.38 133.43 159.54 168.63 176.32 160.88 108.86 95.13
5.58 10.63 14.62 17.23 18.20 19.99 53.04 82.88 76.82 38.04 25.23 31.39 40.82 45.91 46.83 51.86 49.93 47.12 55.36 60.53 58.83 61.47 65.77 64.51 69.17 57.30 69.86 60.14 59.39 56.27 46.04 42.55 38.14 35.69 36.54
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.59 2.03 2.55 2.96 3.13 3.84 4.22 4.82 5.41 5.47 6.77 7.72 7.91 8.34 7.81 8.58 8.08 8.05 5.09 5.86 7.04
Waihapa/ Kaimiro/ Ngaere/Piakau2 Moturoa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.03 3.97 3.11 4.43 4.06 1.55 0.96 0.62 0.54 0.54 0.24 0.26 0.24 0.18 0.23
Notes: 1 For definition of terms used see Glossary, Section K. 2 Piakau has not produced gas since September 1999.
Section E: Gas
Tariki/ Ahuroa
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.17 0.15 0.85 0.66 0.69 0.70 0.54 0.43 0.41 0.36 0.38 0.66 0.66 1.09 1.32 1.06 0.98 0.61 0.52 0.54 0.45 0.55 3 4
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.74 6.85 6.75 8.35 8.97 10.98 11.56 11.95 8.45
Mangahewa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.53 2.15 0.00 0.00 2.93 9.02 7.68 7.27
Ngatoro3
Rimu4
Total
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.07 0.22 0.29 0.26 0.40 0.88 1.22 1.04 1.38 1.47 1.12 0.57 0.71
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.48 0.59 1.56 3.06
5.58 10.63 14.62 17.23 18.20 19.99 53.04 82.88 76.82 54.57 47.41 62.46 103.46 112.35 135.82 168.61 190.90 184.37 204.47 214.90 212.84 222.81 237.55 230.66 222.16 198.84 232.94 236.08 212.35 235.31 233.96 243.57 227.18 172.79 158.98
Includes Goldie well. Includes Kauri well.
99
Energy Data File July 2005
E.2 Net Gas Production by Field* * Excludes gas flared, gas reinjected, LPG extracted, own use and losses
Table E.2a: Net Gas Production by Field1 (PJ) Calendar Year 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Maui
Kapuni
McKee
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 10.03 22.42 31.88 64.94 69.93 93.22 121.68 148.07 143.66 156.56 161.42 159.05 163.68 175.68 168.88 154.66 145.62 164.02 172.32 145.87 175.39 184.64 191.49 174.98 118.79 103.34
4.09 7.80 10.73 12.65 10.50 12.13 34.80 57.08 53.93 23.42 9.03 7.97 9.01 10.42 10.04 10.55 13.13 11.23 11.53 11.42 12.21 19.08 18.62 18.60 17.36 18.29 19.56 20.85 20.31 21.79 24.51 24.87 24.84 23.48 22.69
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.69 2.39 2.93 3.42 3.64 4.46 4.88 5.44 6.03 6.08 7.32 8.27 8.60 9.13 7.99 9.25 8.51 8.59 5.43 6.30 7.67
Waihapa/ Ngaere/Piakau2
Kaimiro/ Moturoa3
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.02 4.37 3.50 4.96 4.35 1.78 1.04 0.71 0.43 0.36 0.23 0.24 0.22 0.17 0.19
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.18 0.16 0.93 0.72 0.75 0.77 0.58 0.47 0.45 0.39 0.41 0.72 0.72 1.09 1.36 1.08 0.90 0.52 0.34 0.42 0.36 0.12
Notes: 1 For definition of terms used see Glossary, Section K. 2 Piakau has not produced gas since September 1999. 3 All gas from the Moturoa field was used for own purposes.
Tariki/ Mangahewa Ahuroa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4.78 8.75 8.63 9.38 9.86 11.74 12.37 14.11 8.84
4
5
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.32 2.39 0.00 0.00 3.13 9.77 8.31 7.88
Ngatoro4
Rimu5
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.83 1.13 1.44 1.30 1.19 0.70 0.20
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.41 1.50 3.42
Total 4.09 7.80 10.73 12.65 10.50 12.13 34.80 57.08 53.93 33.45 31.45 39.85 73.95 80.54 104.11 135.56 164.85 159.06 172.50 177.88 177.61 193.02 204.22 198.95 184.41 174.69 199.10 213.43 187.53 218.21 229.70 241.70 229.62 173.72 154.34
All gas from the Ngatoro field was flared from March 1992 to May 1998. The Ngatoro field includes the Goldie well. All gas from the Rimu field was flared from 1999 to 2001.
Chart E.2a: Annual Net Gas Production by Field (PJ)
Notes: Includes Kaimiro, Mangahewa, Moturoa and Ngatoro (all gas from the Ngatoro field was flared from March 1992 to May 1998). The Ngatoro field includes the Goldie well.
1
100
2
Piakau has not produced gas since September 1999.
Section E: Gas
Energy Data File July 2005
Table E.2b: Net Gas Production by Field1 (Mm3) Calendar Year 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Maui
Kapuni
McKee
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 264.0 601.7 854.0 1,732.4 1,838.0 2,414.7 3,119.0 3,768.9 3,649.7 3,965.9 4,083.6 4,024.4 4,123.8 4,413.1 4,213.8 3,810.4 3,541.6 3,987.6 4,179.4 3,517.1 4,242.5 4,505.8 4,696.9 4,271.3 2,875.3 2,501.4
150.1 286.0 393.3 463.6 384.9 446.8 1,299.6 2,081.3 1,971.9 861.6 338.5 298.5 342.2 390.2 371.4 386.5 480.8 415.6 424.9 425.7 456.1 718.1 706.5 701.4 660.3 692.1 734.1 770.0 752.0 808.6 916.4 936.8 931.0 871.8 844.8
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 16.5 56.6 71.1 82.4 86.5 106.5 117.5 133.3 149.4 150.7 181.4 205.0 213.1 226.1 197.9 224.3 207.9 208.8 131.4 152.9 186.9
Waihapa/ Ngaere/Piakau2 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 22.6 97.5 78.1 110.7 97.1 39.8 23.3 16.3 10.9 8.8 5.6 5.8 5.4 3.7 4.7
Kaimiro/ Moturoa3
Tariki/ Mangahewa Ahuroa
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 4.7 4.2 24.1 18.7 19.5 19.9 15.0 12.0 11.6 10.1 10.7 18.7 18.6 28.2 35.1 28.0 24.2 14.6 10.7 11.5 9.9 3.2
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 103.1 188.8 186.1 229.1 239.5 287.6 303.1 309.8 220.8
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 8.0 59.6 0.0 0.0 80.7 252.4 214.9 203.3
Ngatoro4
Rimu5
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 15.5 21.9 27.9 25.2 23.0 13.7 4.8
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 12.6 41.4 81.7
Ngatoro4
Rimu5
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.55 0.77 0.99 0.89 0.81 0.48 0.17
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.45 1.46 2.89
Total 150.1 286.0 393.3 463.6 384.9 446.8 1,299.6 2,081.3 1,971.9 1,125.6 940.3 1,152.5 2,074.6 2,233.0 2,806.7 3,586.2 4,339.4 4,167.2 4,497.1 4,630.9 4,632.8 5,084.3 5,357.2 5,187.2 4,767.8 4,497.0 5,089.4 5,423.6 4,767.2 5,559.3 5,917.7 6,252.6 5,941.8 4,493.4 4,051.7
Table E.2c: Net Gas Production by Field1 (Bcf) Calendar Year 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Maui
Kapuni
McKee
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 9.32 21.25 30.16 61.18 64.91 85.27 110.15 133.10 128.89 140.05 144.21 142.12 145.63 155.85 148.81 134.56 125.07 140.82 147.60 124.21 149.82 159.12 165.87 150.84 101.54 88.34
5.30 10.10 13.89 16.37 13.59 15.78 45.90 73.50 69.64 30.43 11.95 10.54 12.08 13.78 13.12 13.65 16.98 14.68 15.01 15.03 16.11 25.36 24.95 24.77 23.32 24.44 25.92 27.19 26.56 28.56 32.36 33.08 32.88 30.79 29.83
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.58 2.00 2.51 2.91 3.05 3.76 4.15 4.71 5.27 5.32 6.40 7.24 7.53 7.98 6.99 7.92 7.34 7.37 4.64 5.40 6.60
Waihapa/ Ngaere/Piakau2 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.80 3.44 2.76 3.91 3.43 1.40 0.82 0.57 0.39 0.31 0.20 0.21 0.19 0.13 0.17
Notes:
1 For definition of terms used see Glossary, Section K.
2 Piakau has not produced gas since September 1999.
3 All gas from the Moturoa field was used for own purposes.
Section E: Gas
Kaimiro/ Moturoa3 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.17 0.15 0.85 0.66 0.69 0.70 0.53 0.43 0.41 0.36 0.38 0.66 0.66 1.00 1.24 0.99 0.85 0.52 0.38 0.41 0.35 0.11
Tariki/ Mangahewa Ahuroa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.64 6.67 6.57 8.09 8.46 10.16 10.70 10.94 7.80
4
5
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.28 2.11 0.00 0.00 2.85 8.91 7.59 7.18
Total 5.30 10.10 13.89 16.37 13.59 15.78 45.90 73.50 69.64 39.75 33.21 40.70 73.26 78.86 99.12 126.65 153.24 147.16 158.82 163.54 163.61 179.55 189.19 183.19 168.37 158.81 179.73 191.53 168.35 196.33 208.98 220.81 209.83 158.68 143.08
All gas from the Ngatoro field was flared from March 1992 to May 1998. The Ngatoro field includes the Goldie well. All gas from the Rimu field was flared from 1999 to 2001.
101
Energy Data File July 2005
E.3 Gas Production (PJ) Chart E.3a: Quarterly Gas Production
Chart E.3b: Gas Production Percentages (March Years)
2005
102
2004
Section E: Gas
Energy Data File July 2005
Table E.3: Gas Production (PJ) Calendar Year or Month
Total Gross Natural Gas Production
Gas Reinjected
LPG Extracted
Flared
Production Losses & Own Use
Net Natural Gas Production
Manufactured Gas Production
Total Production*
14.06 15.36 40.22 64.35 59.49 47.14 42.52 56.58 96.76 106.32 133.23 169.24 195.57 189.20 209.45 219.01 217.31 228.31 243.23 237.70 227.84 207.67 243.62 253.43 226.85 253.47 254.17 265.25 248.80 189.66 171.30
0.00 0.00 0.00 0.00 0.00 0.00 5.41 11.08 16.14 18.85 20.01 23.27 19.70 19.63 25.53 29.69 27.90 22.11 25.15 24.79 28.66 19.41 27.67 20.48 21.12 17.74 6.85 3.59 0.50 0.01 0.62
0.11 0.15 0.39 0.55 0.68 1.17 0.85 1.30 1.54 1.74 2.59 4.66 5.44 5.44 5.78 5.74 6.01 7.08 7.69 7.98 8.14 7.61 8.94 9.78 9.54 10.02 10.47 11.54 11.40 9.10 9.13
1.03 1.19 2.29 2.13 0.89 7.76 0.78 0.60 0.47 0.30 1.27 0.76 1.26 1.00 1.50 1.88 2.21 2.45 1.88 1.57 1.85 1.24 2.48 3.97 3.09 1.94 1.64 2.59 1.61 1.08 0.91
2.42 1.90 2.74 4.60 3.99 4.75 4.02 3.75 4.65 4.89 5.25 5.00 4.32 4.07 4.14 3.83 3.59 3.65 4.30 4.41 4.77 4.72 5.43 5.76 5.57 5.56 5.51 5.83 5.67 5.76 6.30
10.50 12.13 34.80 57.08 53.93 33.45 31.45 39.85 73.95 80.53 104.11 135.56 164.85 159.06 172.50 177.88 177.61 193.02 204.21 198.95 184.41 174.68 199.10 213.43 187.53 218.21 229.70 241.70 229.62 173.72 154.34
1.62 1.97 0.00 1.97 1.77 1.70 1.46 1.46 1.31 1.11 0.95 0.70 0.39 0.15 0.11 0.10 0.07 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
12.12 14.10 34.80 59.05 55.69 35.16 32.91 41.31 75.26 81.65 105.06 136.26 165.24 159.21 172.61 177.99 177.68 193.02 204.21 198.95 184.41 174.68 199.10 213.43 187.53 218.21 229.70 241.70 229.62 173.72 154.34
1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2000
Mar Jun Sep Dec
60.21 63.72 67.33 62.92
2.47 1.03 1.07 2.29
2.17 2.63 3.02 2.65
0.32 0.46 0.44 0.42
1.27 1.39 1.38 1.47
53.99 58.20 61.42 56.09
0.00 0.00 0.00 0.00
53.99 58.20 61.42 56.09
2001
Mar Jun Sep Dec
61.40 68.29 74.64 60.92
1.81 0.93 0.45 0.41
2.43 3.12 3.37 2.62
0.65 0.72 0.76 0.47
1.40 1.49 1.60 1.34
55.11 62.04 68.46 56.09
0.00 0.00 0.00 0.00
55.11 62.04 68.46 56.09
2002
Mar Jun Sep Dec
55.84 71.05 65.11 56.81
0.46 0.03 0.00 0.00
2.38 3.21 3.16 2.66
0.42 0.52 0.37 0.30
1.23 1.51 1.51 1.42
51.35 65.78 60.06 52.42
0.00 0.00 0.00 0.00
51.35 65.78 60.06 52.42
2003
Mar Jun Sep Dec
50.10 49.13 53.11 37.33
0.01 0.00 0.00 0.00
1.97 2.39 2.74 2.00
0.33 0.27 0.26 0.22
1.42 1.49 1.50 1.35
46.36 44.99 48.61 33.76
0.00 0.00 0.00 0.00
46.36 44.99 48.61 33.76
2004
Mar Jun Sep Dec
40.86 41.78 45.57 43.08
0.00 0.00 0.28 0.34
1.95 2.40 2.61 2.18
0.23 0.19 0.22 0.27
1.46 1.31 1.81 1.71
37.22 37.87 40.66 38.59
0.00 0.00 0.00 0.00
37.22 37.87 40.66 38.59
2005
Mar
36.07
0.33
1.87
0.20
1.51
32.15
0.00
32.15
Year Mar 2004 180.43 Ended Mar 2005 166.51
0.00 0.96
9.08 9.06
0.98 0.88
5.80 6.34
164.57 149.27
0.00 0.00
164.57 149.27
* Note definition changes since Energy Data File January 1997. Total production includes transmission losses.
1 PJ
G.C.V. ~ 0.904 PJ
Section E: Gas
N.C.V.
(See Fuel Properties Table L.6 for detail.)
103
Energy Data File July 2005
E.4 Gas Demand Chart E.4a: Quarterly Gas Demand
Chart E.4b: Gas Demand Share (March Years)
2005
104
2004
Section E: Gas
Energy Data File July 2005
Table E.4: Gas Demand (PJ) Calendar Year or Month 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
*
Total Production
Transmission Losses*
Direct Sales
Reticulated Sales**
Stock Change
12.12 14.10 34.80 59.05 55.69 35.16 32.91 41.31 75.26 81.65 105.06 136.26 165.24 159.21 172.61 177.99 177.68 193.02 204.21 198.95 184.41 174.68 199.10 213.43 187.53 218.21 229.70 241.70 229.62 173.72 154.34
0.53 0.99 0.93 -0.31 -1.06 -0.46 0.53 0.49 0.44 0.50 0.04 2.05 -1.29 -1.63 -0.75 -1.74 -1.38 -1.36 -1.23 0.12 0.17 0.22 0.23 0.28 0.41 0.39 0.54 0.60 0.61 0.80 0.73
2.09 0.24 20.54 44.49 42.38 21.79 15.16 20.12 49.24 49.69 69.47 95.47 123.68 119.00 133.18 139.81 140.20 151.80 164.82 158.87 142.07 132.03 154.02 161.23 131.15 157.00 170.24 177.53 165.15 106.87 90.38
9.49 12.87 13.34 14.87 14.37 13.69 17.06 20.73 25.53 31.46 35.42 38.74 42.58 41.52 39.87 39.66 38.60 42.16 40.32 39.65 41.89 42.18 44.50 51.65 55.93 60.57 58.88 63.11 63.51 65.85 63.12
0.00 0.00 0.00 0.00 0.00 0.14 0.16 -0.03 0.05 -0.01 0.13 0.00 0.27 0.33 0.32 0.25 0.27 0.42 0.31 0.31 0.29 0.25 0.36 0.28 0.04 0.24 0.04 0.45 0.35 0.20 0.10
2000
Mar Jun Sep Dec
53.99 58.20 61.42 56.09
0.13 0.13 0.13 0.13
39.14 43.86 46.06 41.18
14.80 14.13 15.15 14.80
-0.09 0.07 0.08 -0.02
2001
Mar Jun Sep Dec
55.11 62.04 68.46 56.09
0.15 0.15 0.15 0.15
41.12 45.26 50.33 40.83
13.79 16.45 17.82 15.04
0.06 0.18 0.16 0.06
2002
Mar Jun Sep Dec
51.35 65.78 60.06 52.42
0.15 0.15 0.15 0.15
36.12 49.81 43.34 35.89
14.92 15.71 16.49 16.39
0.16 0.12 0.09 -0.01
2003
Mar Jun Sep Dec
46.36 44.99 48.61 33.76
0.20 0.20 0.20 0.20
31.65 28.86 29.69 16.67
14.46 15.83 18.69 16.87
0.05 0.10 0.03 0.02
2004
Mar Jun Sep Dec
37.22 37.87 40.66 38.59
0.18 0.18 0.18 0.18
22.47 21.91 23.22 22.79
14.53 15.78 17.21 15.60
0.04 0.00 0.05 0.01
2005
Mar
32.15
0.18
17.29
14.62
0.06
Year Ended
Mar 2004 Mar 2005
164.57 149.27
0.78 0.73
97.68 85.21
65.92 63.21
0.19 0.12
Estimated.
** Reticulated sales (calculated) include cogeneration. 1 PJ
G.C.V. ~ 0.904 PJ
Section E: Gas
N.C.V.
(See Fuel Properties Table L.6 for detail.)
105
Energy Data File July 2005
E.5 CNG Sales Chart E.5: Quarterly CNG Sales
Table E.5: CNG Sales (PJ) Calendar Year 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
PJ/Year 1.103 2.568 4.010 5.850 5.650 4.973 4.167 3,257 2,650 2.662 2.461 2.275 1.834 1.423 1.056 0.756 0.508 0.037 0.073 0.143 0.191 0.245 0.216
PJ/Quarter 2000
Mar Jun Sep Dec
0.015 0.025 0.020 0.013
2002 Mar Jun Sep Dec
0.033 0.052 0.060 0.046
2004 Mar Jun Sep Dec
0.043 0.064 0.067 0.042
2001
Mar Jun Sep Dec
0.012 0.046 0.050 0.035
2003 Mar Jun Sep Dec
0.054 0.067 0.075 0.049
2005 Mar
0.047
Year Mar 2004 0.234 Ended Mar 2005 0.220
* Estimated from July 2000 to March 2005.
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Section E: Gas
Energy Data File July 2005
E.6: Gas Consumption and Prices by Sectors
In this section, quarterly gas consumption, gas sales revenue and gas customer numbers reported by the gas retailers for the five calendar years (2000 to 2004) are used to derive average unit prices ($/GJ) and average consumption (GJ). This is summarised along with total consumption for the three main sectors: residential, commercial and industrial. The statistical information which is summarised for the five year period are from the following gas retailers: 1) Contact Energy (2000–2004); 2) Genesis Energy (2002–2004); 3) Natural Gas Corporation (2000–2004); 4) Nova Gas (2000–2004) and 5) Wanganui Gas (2000–2004). NGC ceased gas retailing to the residential sector in December 2002 and Nova Gas has only commercial and industrial customers. The information for a smaller retailer serving mainly commercial customers in Auckland accounting for a few PJ is not part of this statistical collection. During 2004 calendar year, the industrial sector (including for electricity generation and petrochemical production) accounted for 90 percent of the gas consumption share while the commercial sector and the residential sector had only a 6 and 4 percent share, respectively. The residential sector however, was responsible for 95 percent (or about 220,000) of the consumers while the industrial sector comprised about 1% (1,700) and the commercial sector about 4% (9,000) of the consumers (Charts E.6a and E.6b). Over the 2000 to 2004 period, the number of residential consumers rose from about 190,000 to 220,000 with average consumption declining from about 38 GJ to about 31 GJ and the average unit prices, including GST, rising from about $19 per GJ to about $26 per GJ (Table E.6 and Chart E.7). During the same period, the number of commercial consumers declined from
Chart E.6a: Share of Consumption by Sector during 2004
about 13,000 to 9,000 with consumption averaging about 1,000 GJ to 1,200 GJ and average prices, excluding GST, increased from about $8.50 per GJ to about $9.20 per GJ (Table E.7 and Chart E.8). The number of industrial consumers rose from under 1,000 to about 1,700 during the 2000 to 2004 period when the average consumption declined from about 260,000 GJ to 80,000 GJ and the average unit prices, excluding GST, rose from about $3.00 per GJ to about $4.50 per GJ (Table E.8 and Chart E.9). More detailed breakdown of gas consumption by key sub-sectors (according to ANZSIC codes) during 2002 to 2004 indicates that total consumption by the petroleum and chemical products sectors (ie, ANZSIC code C25) declined from 97 PJ in 2002 to about 51 PJ in 2004 while average unit prices rose from $2.60 to $2.90 per GJ and total consumption by the electricity (generation), gas and water sectors (ie, ANZSIC code D) also declined from about 91 PJ in 2002 to about 60 PJ in 2004 when average unit prices for this sector rose from about $3.90 per GJ to over $5.20 per GJ in 2004 (Table E.10). Total gas consumption by all sectors declined from about 230 PJ in 2000 to about 150 PJ in 2004 after rising to about 245 PJ in 2001 while total gas consumer numbers rose from about 200,000 in 2000 to about 230,000 in the 2004 calendar year. Average unit prices across all three sectors rose from about $4.00 per GJ to $5.70 per GJ when average annual consumption halved from about 1,200 GJ to about 660 GJ mainly due to declining industrial sector consumption (Table E.9 and Chart E.10).
Chart E.6b: Share of Consumers by Sector during 2004
Residential 4%
Commercial 4% Industrial 1%
Commercial 6%
Industrial 90%
Section E: Gas
Residential 95%
107
Energy Data File July 2005
Table E.6: Gas Consumption by the Residential Sector Residential Calendar Year or Quarter 2000 2001 2002 2003 2004
Consumption GJ (000)
Sales $(000)
Average Price (incl. GST) $/GJ
Number of Consumers
Average Consumption GJ
7,172 7,207 6,786 6,870 6,707
135,591 136,246 118,672 161,396 171,318
18.91 18.90 17.49 23.49 25.54
187,117 175,172 199,013 211,478 219,367
38.33 41.14 34.10 32.49 30.57
2000
Mar Jun Sep Dec
1,316 1,419 2,461 1,976
24,497 27,240 44,281 39,572
18.62 19.20 17.99 20.03
205,990 185,815 182,020 174,643
6.39 7.64 13.52 11.31
2001
Mar Jun Sep Dec
1,586 1,294 2,503 1,824
31,632 25,600 45,619 33,394
19.94 19.78 18.23 18.31
172,824 173,697 181,124 173,043
9.18 7.45 13.82 10.54
2002
Mar Jun Sep Dec
1,516 1,569 2,004 1,697
29,838 29,869 37,473 21,492
19.68 19.04 18.70 12.66
173,714 203,167 208,485 210,684
8.73 7.72 9.61 8.05
2003
Mar Jun Sep Dec
1,300 1,499 2,877 1,194
32,277 48,920 51,712 28,486
24.83 32.63 17.97 23.86
211,248 209,346 209,731 215,585
6.15 7.16 13.72 5.54
2004
Mar Jun Sep Dec
817 1,727 2,704 1,459
26,307 40,613 60,046 44,353
32.20 23.52 22.21 30.40
216,319 215,138 220,078 225,933
3.78 8.03 12.29 6.46
6,870 6,707
161,396 171,318
23.49 25.54
211,478 219,367
32.49 30.57
Year Dec 2003 Ended Dec 2004
Chart E.7: Average Residential Gas Price1 and Average Consumption
Note: 1
Including GST.
108
Section E: Gas
Energy Data File July 2005
Table E.7: Gas Consumption by the Commercial Sector Commercial Calendar Year or Quarter 2000 2001 2002 2003 2004
Consumption GJ (000)
Sales $(000)
Average Price (excl.GST) $/GJ
Number of Consumers
Average Consumption GJ
14,458 13,705 13,491 9,917 9,226
123,133 114,314 119,209 96,402 84,743
8.52 8.34 8.84 9.72 9.19
12,361 11,228 11,072 10,428 8,990
1,170 1,220 1,218 951 1,026
2000
Mar Jun Sep Dec
3,489 3,681 4,227 3,061
29,702 31,050 34,392 27,989
8.51 8.44 8.14 9.14
13,527 12,265 12,500 11,151
258 300 338 275
2001
Mar Jun Sep Dec
2,551 4,209 4,132 2,813
21,766 33,250 34,655 24,643
8.53 7.90 8.39 8.76
11,440 11,480 11,524 10,468
223 367 359 269
2002
Mar Jun Sep Dec
2,359 4,278 3,888 2,966
21,915 35,163 33,962 28,169
9.29 8.22 8.74 9.50
9,917 11,522 11,375 11,474
238 371 342 259
2003
Mar Jun Sep Dec
1,667 2,456 3,651 2,143
18,196 25,636 32,524 20,046
10.92 10.44 8.91 9.35
10,652 10,453 10,355 10,250
156 235 353 209
2004
Mar Jun Sep Dec
1,849 2,501 2,884 1,992
16,493 20,694 26,917 20,639
8.92 8.27 9.33 10.36
8,968 9,296 8,981 8,714
206 269 321 229
9,917 9,226
96,402 84,743
9.72 9.19
10,428 8,990
951 1,026
Year Dec 2003 Ended Dec 2004
Chart E.8: Average Commercial1 Gas Price2 and Average Consumption
Notes:
1 Includes transport and cogeneration.
2 Excludes GST.
Section E: Gas
109
Energy Data File July 2005
Table E.8: Gas Consumption by the Industrial Sector Industrial Calendar Year or Quarter 2000 2001 2002 2003 2004
Consumption GJ (000)
Sales $(000)
Average Price (excl. GST) $/GJ
Number of Consumers
Average Consumption GJ
210,027 223,349 207,616 157,161 136,514
660,554 761,976 698,428 688,891 613,569
3.15 3.41 3.36 4.38 4.49
903 851 996 1,369 1,702
232,524 262,378 208,502 114,842 80,220
2000
Mar Jun Sep Dec
48,944 52,621 54,584 53,879
166,815 162,551 162,292 168,895
3.41 3.09 2.97 3.13
1,003 902 858 850
48,797 58,338 63,618 63,387
2001
Mar Jun Sep Dec
53,512 57,726 60,211 51,900
170,011 200,979 205,537 185,448
3.18 3.48 3.41 3.57
797 982 1,050 576
67,142 58,785 57,344 90,104
2002
Mar Jun Sep Dec
46,018 60,128 53,852 47,618
169,088 187,128 183,516 158,695
3.67 3.11 3.41 3.33
854 1,228 1,132 769
53,885 48,964 47,572 61,922
2003
Mar Jun Sep Dec
43,255 40,074 44,047 29,785
176,802 192,314 198,134 121,641
4.09 4.80 4.50 4.08
1,424 1,364 1,356 1,330
30,376 29,380 32,484 22,395
2004
Mar Jun Sep Dec
34,535 32,986 34,642 34,351
140,503 144,367 162,074 166,625
4.07 4.38 4.68 4.85
1,697 1,731 1,708 1,671
20,350 19,056 20,282 20,557
157,161 136,514
688,891 613,569
4.38 4.49
1,369 1,702
114,842 80,219
Year Dec 2003 Ended Dec 2004
Chart E.9: Average Industrial1 Gas Price and Average Consumption
Note: 1
Excludes GST.
110
Section E: Gas
Energy Data File July 2005
Table E.9: Gas Consumption by All Sectors All Sectors Calendar Year or Quarter 2000 2001 2002 2003 2004
Consumption GJ (000)
Sales $(000)
231,657 244,261 227,893 173,948 152,447
919,278 1,012,535 936,309 946,689 869,630
Number of Consumers
Average Consumption GJ
3.97 4.15 4.11 5.44 5.70
200,381 187,251 211,080 223,274 230,059
1,156 1,304 1,080 779 663
Average Price 1 $/GJ
2000
Mar Jun Sep Dec
53,749 57,721 61,272 58,916
221,014 220,841 240,965 236,457
4.11 3.83 3.93 4.01
220,520 198,982 195,378 186,644
244 290 314 316
2001
Mar Jun Sep Dec
57,649 63,229 66,846 56,537
223,409 259,829 285,812 243,485
3.88 4.11 4.28 4.31
185,061 186,159 193,698 184,087
312 340 345 307
2002
Mar Jun Sep Dec
49,893 65,975 59,744 52,281
220,841 252,159 254,951 208,357
4.43 3.82 4.27 3.99
184,485 215,917 220,992 222,927
270 306 270 235
2003
Mar Jun Sep Dec
46,222 44,029 50,575 33,122
227,275 266,870 282,371 170,173
4.92 6.06 5.58 5.14
223,324 221,163 221,442 227,165
207 199 228 146
2004
Mar Jun Sep Dec
37,201 37,214 40,230 37,802
183,303 205,673 249,037 231,617
4.93 5.53 6.19 6.13
226,984 226,165 230,767 236,318
164 165 174 160
173,948 152,447
946,689 869,630
5.44 5.70
223,274 230,059
779 663
Year Dec 2003 Ended Dec 2004
Chart E.10: Annual Gas Consumption by Sector
1
Natural gas prices for ‘all sectors’ are weighted average prices calculated for each quarter, based on information provided by the retailers of natural gas. The average prices include GST for the residential sector and exclude GST for the commercial and industrial sectors.
Section E: Gas
111
112
Table E.10: Gas End Use for 2002, 2003 and 2004 2002 ANZSIC
Consumption GJ (000)
INDUSTRIAL2 ....................................
Average Price 1 $/GJ
2003
No. of Average Consumers Consumption GJ
Consumption GJ (000)
Average Price 1 $/GJ
2004
No. of Average Consumption Consumers Consumption GJ GJ (000)
Average Price 1 $/GJ
No. of Consumers
Average Consumption GJ
80,220
207,616
3.4
996
208,502
157,161
4.4
1,369
114,779
136,514
4.5
1,702
Agriculture, forestry and fishing
A
799
6.5
146
5,473
1,341
6.7
82
16,354
1,628
7.1
192
8,490
Mining
B
134
4.7
5
29,778
168
5.6
8
22,400
191
5.8
9
22,471
Food, textile, footwear and leather
C21–C22
8,990
4.9
270
33,265
12,568
5.7
292
43,041
10,491
6.1
415
25,295
Wood & paper products, printing & publishing
C23–C24
8,521
3.9
115
74,096
8,122
4.9
93
87,569
8,912
5.6
154
57,776
C25
96,675
2.6
75
1,284,718
46,522
3.2
72
650,657
51,434
2.9
81
638,928
Petroleum, coal and chemical products 3
C26–C29
1,262
6.1
298
4,238
2,106
6.8
464
4,541
3,329
6.8
431
7,728
Electricity, gas and water
D
91,201
3.9
36
2,515,890
86,238
4.7
314
274,862
60,387
5.2
282
214,328
Construction
E
34
9.0
51
670
96
10.5
46
2,087
142
7.6
140
1,018
13,491
8.8
11,072
1,218
9,917
9.7
10,428
951
9,226
9.2
8,990
1,026
10,786
9.3
8,641
1,248
3,732
12.7
8,535
437
2,740
9.9
4,543
603
I
191
7.6
58
3,322
245
7.9
50
4,876
216
8.7
118
1,834
COMMERCIAL ................................ 4
Wholesale and retail trade Transport and storage Communication services
F, G, H J, K, L
201
9.7
314
640
350
13.4
314
1,116
464
12.7
721
644
Government (including foreign), administration and defence
M
292
7.4
172
1,703
432
9.8
180
2,407
508
10.0
280
1,813
Education, cultural, recreational and personal services
N, P, Q
915
9.2
1,656
553
3,794
7.1
1,030
3,683
3,710
8.4
2,576
1,440
Health and community services
O
1,106
4.6
232
4,772
1,364
8.2
319
4,279
1,588
8.4
753
2,110
NON-RESIDENTIAL ..........................
221,107
3.7
12,068
18,322
167,078
4.7
11,797
14,163
145,740
4.8
10,692
13,631
RESIDENTIAL ....................................
6,786
17.5
199,013
34
6,870
23.5
211,478
32
6,707
25.5
219,367
31
TOTAL SALES ................................
227,893
4.1
211,080
1,080
173,948
5.4
223,274
779
152,447
5.7
230,059
663
5
Notes: 1 2
Section E: Gas
3
4 5
Residential average prices include GST, while industrial and commercial average prices do not include GST. Industrial figures provided here do not agree with the industrial figures in the energy balance tables (Section B). The industrial figures in the energy balance tables are calculated by the reticulated sales less gas consumed by the residential, commercial and transport sectors. The ANZSIC category C25 includes non-energy uses (natural gas used as feedstock for the production of methanol and ammonia/urea), as well as energy sources for petroleum refining and the production of petroleum and coal products, fertiliser, industrial gases and synthetic resin, organic industrial chemicals and inorganic industrial chemicals. Includes transport and cogeneration. Total market natural gas prices are a weighted average price, based on information provided by the retailers of natural gas.
Energy Data File July 2005
Metal, non-metallic, machinery products and other manufacturing
Energy Data File July 2005
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Section E: Gas
113
