Energy Data File January 2005
Energy Data File January 2005
E. Gas Figure E.1: Gas Flows for September Year 20041 By gross production:
FIELDS By net production:
5.0%
64.2%
16.5%
Mangahewa
Maui
Kapuni
Ngatoro2
5.4%
65.7%
15.3%
0.2%
Todd Taranaki 100%
Shell Explo 38.75% EPIL 20.00% Shell (Petro) 18.75% OMV 10.00% Todd Energy 6.25% TOPC 6.25%
Shell (Petro) 50% Todd Energy 50%
Operator: Shell Todd Oil Services
Operator: Shell Todd Oil Services
Operator: Shell Todd Oil Services
4.6%
McKee
4.8%
PRODUCERS
WHOLESALER
The Crown
0.3%
0.2%
7.3%
1.9%
Kaimiro
TAWN
Rimu3
0.1%
6.7%
1.8%
Greymouth 87% Southern 9% Greymouth Petro 4%
Greymouth 100%
Southern Petro 96.76% Swift Energy 3.24%
Swift Energy 100%
Operator: Greymouth
Operator: Greymouth
Operator: Swift Energy
Operator: Swift Energy
EGCL
EFNZL
Contact Energy
Shell (Petro) and Todd Energy
NGC
TRANSMITTERS
Genesis Power
(high pressure)
DISTRIBUTORS (low pressure)
RETAILERS
Powerco, Vector Genesis Energy4
NGC, Nova Gas, Wanganui Gas, Others5
Contact Energy
Major users supplied directly from the transmission system
CONSUMERS
By consumption: (calculated)
Users supplied from distribution systems
BHP NZ Steel Carter Holt Harvey Degussa Peroxide Fonterra Co-operative Todd Energy/ Kiwi Cogeneration NZ Refinery Company Southdown Cogeneration Tasman Pulp and Paper and some other companies
Methanex Other industry, commercial, residential, transport (as CNG)
43.4%
Chemical methanol manufacture
26.1%
Ballance AgriNutrients (Kapuni) Limited
Contact Energy Genesis Power
Ammonia/urea manufacture
Electricity generation
4.8%
25.7%
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 30 September 2004 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 and E Gas.
86
Section E: Gas
Energy Data File January 2005
Overview of New Zealand’s Gas Industry All statistics in this commentary apply to the year ended September 2004, and comparisons apply to that year relative to the year ended September 2003, unless otherwise specified. Overall comments are related to actual and proposed developments in the gas industry as at January 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. The rest is owned by a spread of public shareholders (33.95%). In July 2004, Australian company Origin Energy bought a 51.2% stake in Wellington-based Contact Energy for NZ$1.7 million or $5.67 per share from Californian-based Edison Mission Energy. Two petroleum mining permits were granted by Crown Minerals in 2004. On 8 October, 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 hydro-carbon reserves of 700 Bcf gas and 42.8 mmbbls of condensate. The Pohokura joint venture partners are Shell Exploration NZ Ltd (29.6673%), Shell (Petroleum Mining) Company Ltd (18.33%), Todd Pohokura Ltd (25.999%) and OMV NZ Ltd (25.999%). In September 2004, a 5.99 sq-km onshore petroleum mining permit for the production of gas and condensate was granted over the Kahili field. 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 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. Vector holds 16% of the Auckland gas market with 72,000 consumers. It has 200 km of fibre optic high-speed broadband voice and data communications in the Auckland and Wellington regions. (Source: Various issues of New Zealand Petroleum News – Ministry of Economic Development).
Developments Substantial development activities during 2004 included the granting of the Pohokura mining permit and progress on development plans for the Kupe oil Section E: Gas
and gas field. The drilling of production wells in the Pohokura field is scheduled to commence in mid2005, with initial production expected to be 50 PJ of gas and 3 mmbbls of condensate per annum. 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 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 313km onshore Maui pipeline from the Maui production station in south Taranaki to Huntly power station (1,000MW), 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 long-term contracts for the supply of Kupe, Mangahewa, McKee and Pohokura gas. The $520 million project is one of the largest infra-structure 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 News – Ministry of Economic Development).
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. 87
Energy Data File 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 first $750,000,000 of gross sales (offshore) for discoveries made during the period (was 20%). 3. APR of 15% for 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 at any time in the future. Costs incurred prior to the granting of a petroleum mining permit will 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. Taxation The so called “183 day rule” has been amended so 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. Other initiatives to promote exploration in New Zealand included the securing of Government backing for a $15 million seismic data acquisition project. In February 2005 a 4,200 km Crown-funded 2D seismic acquisition campaign commenced over the central and northern parts of the East Coast Basin. This survey will significantly increase understanding of the oil and gas potential of the East Coast Basin. The data acquired, and the results of subsequent geotechnical studies, will be released to industry free of charge to encourage further exploration in those areas. Figure E.1 presents a schematic of natural gas ownership and physical flows in New Zealand for the September year 2004, with proportions of gas produced by the different fields and consumed by major user/supplier categories.
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. 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 oil and gas (including condensate and naphtha). 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 81% of total production. They are both operated by Shell Todd Oil Services Limited. Other fields in production during the year to September 2004 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 Kaimiro, owned by Greymouth Petroleum Acquisition Company Limited. Together they provide the remaining 19% of total gas production. (See Chart E.1a.) As Chart E.1a illustrates, the Maui field was the major source of gas production, providing 64.2% of New Zealand’s gross gas production in the year ended 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 88
* Includes the Goldie well. ** Others include Mangahewa and Rimu fields.
Section E: Gas
Energy Data File January 2005
September 2004. The Kapuni field produced 16.5%, Tariki/Ahuroa 7.1%, Mangahewa 5.0%, McKee 4.6%, Rimu (including Kauri well) 1.9%, Ngatoro (including Goldie well) 0.3%, Kaimiro 0.2%, and Waihapa/Ngaere 0.2% of total gas production. The Moturoa field ceased producing gas in November 2001. Total New Zealand gas production in the year ended September 2004, excluding gas reinjected or flared, and LPG extracted was 155.4 PJ, a decline of 22% compared with 198.2 PJ in the year ended September 2003. This was mainly due to a significant decrease in production at Maui (27%). Other fields to display declining production over this period were Ngatoro (including Goldie well, 53% decline), Tariki/Ahuroa (31%), Kamiro (28%), Waihapa/Ngaere (10%), Mangahewa (2.6%) and Kapuni (2.3%). Gas reinjected for the September year 2004 was 0.29 PJ higher than the year ended September 2003 level of 0.01PJ. The Rimu and McKee fields increased their production by 107% and 14% respectively, compared with the year ended September 2003.
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 transmission system. NGC also operates extensive gas distribution and retail operations in the North Island Chart E.1b: Gas Use by Sector (September Years)
of New Zealand. There are five gas distributors: NGC Infrastructure, Nova Gas, Wanganui Gas, Vector and Powerco, and eight retailers: NGC (retails only to larger commercial and industrial customers), Nova Gas, Wanganui Gas, Contact Energy (gas wholesaler/ retailer), Genesis Energy, Mercury Energy, Bay of Plenty Electricity and E Gas.
Liquefied petroleum gas In addition to natural gas, the gas industry produced 8.6 PJ of liquefied petroleum gas (LPG) in the year ended September 2004, 9% lower than the year ended September 2003 level of 9.5 PJ. Of the 8.6 PJ of production, 0.7 PJ was exported and 7.6 PJ was used in New Zealand. In the year ended September 2004, 0.5 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.
Petrochemicals The petrochemicals sector used around 31% of New Zealand’s natural gas during the year ended September 2004 (in Methanex’s methanol plants at Motunui and Waitara, and the Ballance Agri-Nutrients (Kapuni) ammonia/urea plant) compared with 32% in the year ended September 2003. This was mainly due to a reduction in Methanex’s entitlements for Maui gas. Crude methanol is produced from natural gas and then distilled into high (“AA”) grade methanol. Methanex New Zealand produced 304,000 tonnes of methanol during the third quarter 2004 compared with 229,000 tonnes during the second quarter 2004. The company planned to produce approximately 250,000 tonnes during the fourth quarter 2004. Methanex has the potential to produce up to approximately 375,000 tonnes of methanol. Ballance Agri-Nutrients (Kapuni) Limited (previously Petrochem Limited) manufactures ammonia
Section E: Gas
89
Energy Data File January 2005
and urea from natural gas. The ammonia/urea plant uses Maui gas for fuel and a mixture of Maui and Kapuni LTS gas as a feedstock. Gas used in ammonia and urea production increased by 3.0% compared with the year ended September 2003.
Chart E.1c: Reticulated End Use by Sector
Electricity generation Gas used for electricity generation (including cogeneration) was about 41% of New Zealand’s natural gas produced during the year ended September 2004. Of the 41% of gas used for generation, 26% was used for electricity generation and 15% 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 41% and 9.9% to 38 PJ and 22 PJ respectively in the year ended September 2004, compared with the year ended September 2003 levels of 65 PJ and 24 PJ respectively.
Reticulated end use The remaining 28% of New Zealand’s gas use was reticulated throughout the North Island (by NGC) through a high-pressure 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 42.3 PJ of consumer energy (excluding cogeneration) reticulated in the year ended September 2004, 22.4 PJ (53.1%) was used by industry, 12.7 PJ (29.9%) by the commercial sector, 7.0 PJ (16.5%) by the residential sector and 0.2 PJ (0.5%) in transport (as CNG), as Chart E.1c illustrates.
90
Annual per capita end use of gas is 10.4 GJ (284 m3). Reticulated demand (observed, excluding cogeneration) increased 2.5% to 42.3 PJ from 41.3 PJ in the year ended September 2003. Chart E.4a (page 100) shows gas demand by direct major users (petrochemicals and electricity generation) and reticulated end use (industrial, commercial, residential and transport) from the September quarter 1974 to the September quarter 2004 and Chart E.4b compares gas demand share for September years 2003 and 2004. Gas demand by petrochemicals and electricity generation was about 85 PJ, 33% lower than the year ended September 2003 level of 126 PJ, while gas demand by reticulated end use (including cogeneration) increased by 2.1% to 64 PJ. Chart E.4b shows that in the year ended September 2004 gas demand by direct and reticulated users was 57% and 43% respectively, compared with 66% and 34% in the year ended September 2003. This was mainly due to a decline in gas consumption by Methanex and electricity generation.
Section E: Gas
Section E: Gas
Notes:
165.5
149.7
3
companies
Distribution Gas distribution
7.0
Residential
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.
12.7
22.4 Commercial
Other Industry Uses
Cogenerators
3
Observed 148.8
42.3
21.7
Genesis Power Limited
Contact Energy Limited
Includes the Goldie well.
Statistical Calculated difference 0.9 149.7 5
149.7
38.5
Electricity generation
Ballance Agri-Nutrients (Kapuni) Limited
Methanex New Zealand Limited
Includes the Kauri well.
Net production
Westech Energy
Todd Taranaki
Todd Petroleum and Shell
Swift Energy New Zealand Limited
Direct supply
46.3
2
Swift Energy New Zealand Limited
Shell Todd Oil Services Limited
New Zealand Oil and Gas Services Limited
Natural Gas Corporation of New Zealand Limited (NGC)
Direct supply
Non-energy use
USE
1
Gross production
Waihapa/Ngaere
Tariki/Ahuroa
Rimu 2
Ngatoro 1
McKee
Maui
Greymouth Petroleum Acquisition Company Limited
Maui Development Limited
Kapuni
Mangahewa
Transmission
Field operators
Gas flared and own use 6.5
LPG extracted 9.0
Gas reinjected 0.3
CONVEYANCE
Kaimiro
Fields
PRODUCTION
Petajoules (to approximate vertical scale)
Transport 0.2
BHP 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
Figure E.2: Gas Flow Summary for September Year 2004
Energy Data File January 2005
91
Energy Data File January 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
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
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
0.00 0.00 0.00 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
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
Notes: 1 For definition of terms used see Glossary, Section K, page 156. 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
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 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
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
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 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
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
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
Includes Goldie well. Includes Kauri well.
Chart E.1a1: Annual Gross Gas Production by Field (PJ) Others1 Waihapa/Ngaere/Piakau
2
McKee
Maui
Kapuni
Tariki/Ahuroa
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.
92
Section E: Gas
Energy Data File January 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
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
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
0.0 0.0 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
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
Notes: 1 For definition of terms used see Glossary, Section K, page 156. 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 67% of New Zealand’s total gas production in the calendar year 2003. Charts E.1a1 (page 92) and E.2a (page 95) show gross and net gas production respectively by field from 1970 to 2003. Gross gas production is total gas production after the first separation point. See Figure H.1, page 130. Net gas production is the difference between gross gas production and the amount of gas flared, gas reinjected, LPG extracted, own use and losses.
Section E: Gas
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 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
Mangahewa Ngatoro3 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 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
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 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
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 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.3 0.3 13.7 16.7 44.1
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
Includes Goldie well. Includes Kauri well.
Total New Zealand net gas production fell 24% to 174 PJ in 2003, compared with 230 PJ in the year ended December 2002. Overall, the amount of gas flared, gas reinjected, LPG extracted, own use and losses has generally been increasing since around 1978, but decreased by 17% to 16 PJ between 2002 and 2003. Of the total 16 PJ, 54% or 9 PJ relates to the Maui field, 25% or 4 PJ to the Kapuni field and the remaining 21% 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.
93
Energy Data File January 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
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
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
0.00 0.00 0.00 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
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
Notes: 1 For definition of terms used see Glossary, Section K, page 156. 2 Piakau has not produced gas since September 1999.
94
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 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
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 0.53 2.15 0.00 0.00 2.93 9.02 7.68
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 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
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 0.48 0.59 1.56
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
Includes Goldie well. Includes Kauri well.
Section E: Gas
Energy Data File January 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
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
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 24.86 24.74 23.31
0.00 0.00 0.00 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
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
0.00 0.00 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
Notes: 1 For definition of terms used see Glossary, Section K, page 156. 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
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
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
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.51 1.66
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
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
Section E: Gas
2
Piakau has not produced gas since September 1999.
95
Energy Data File January 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
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
150.1 286.0 393.3 463.6 384.9 446.8 1,299.6 2,081.3 1,971.9 861.6 338.5 298.5 342.2 390.2 371.4 386.5 480.8 415.6 424.9 425.7 456.1 718.1 706.5 701.4 660.3 692.1 734.1 770.0 752.0 808.6 916.4 936.7 927.4 865.8
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
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
Notes: 1 For definition of terms used see Glossary, Section K, page 156. 2 Piakau has not produced gas since September 1999. 3 All gas from the Moturoa field was used for own purposes.
96
Kaimiro/ Moturoa3 0.0 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
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 0.0 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
4
5
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 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
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
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 12.7 40.9
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 6,252.5 5,938.2 4,486.9
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.
Section E: Gas
Energy Data File January 2005
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
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
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 32.75 30.58
0.00 0.00 0.00 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
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
Notes: 1 For definition of terms used see Glossary, Section K, page 156. 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
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
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
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
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.45 1.44
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 99.12 126.65 153.24 147.16 158.82 163.54 163.61 179.55 189.19 183.19 168.37 158.81 179.73 191.53 168.35 196.33 208.98 220.80 209.70 158.45
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.
97
Energy Data File January 2005
E.3 Gas Production (PJ) Chart E.3a: Quarterly Gas Production
Chart E.3b: Gas Production Percentages (September Years)
2004
98
2003
Section E: Gas
Energy Data File January 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
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
0.11 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
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
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
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
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
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
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 1999
Sep Dec
71.22 61.51
5.33 3.00
3.00 2.33
0.36 0.52
1.51 1.32
61.03 54.34
0.00 0.00
61.03 54.34
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
40.86 41.78 45.57
0.00 0.00 0.28
1.95 2.40 2.61
0.23 0.19 0.22
1.46 1.36 1.53
37.22 37.82 40.94
0.00 0.00 0.00
37.22 37.82 40.94
Year Sep 2003 209.14 Ended Sep 2004 165.54
0.01 0.29
9.75 8.96
1.16 0.86
5.84 5.70
192.38 149.74
0.00 0.00
192.38 149.74
* 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.)
99
Energy Data File January 2005
E.4 Gas Demand Chart E.4a: Quarterly Gas Demand
Chart E.4b: Gas Demand Share (September Years)
2004
100
2003
Section E: Gas
Energy Data File January 2005
Table E.4: Gas Demand (PJ) Calendar Year or Month
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
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
2.09 0.24 20.54 44.49 42.38 21.79 15.16 20.12 49.24 49.69 69.47 95.47 123.68 119.00 133.18 139.81 140.20 151.80 164.82 158.87 142.07 132.03 154.02 161.23 131.15 157.00 170.24 177.53 165.15 106.81
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 65.91
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
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
*
1999
Sep Dec
61.03 54.34
0.10 0.10
43.67 38.15
17.18 16.05
0.08 0.04
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
37.22 37.82 40.94
0.20 0.20 0.20
22.64 22.28 23.23
14.34 15.35 17.46
0.04 0.00 0.05
Year Ended
Sep 2003 Sep 2004
192.38 149.74
0.75 0.80
126.08 84.82
65.37 64.02
0.18 0.10
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.)
101
Energy Data File January 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
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 0.073 0.143 0.191 0.182 0.174
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
2001
Mar Jun Sep Dec
0.012 0.046 0.050 0.035
2003 Mar Jun Sep Dec
0.040 0.050 0.044 0.048
2004 Mar Jun Sep
0.044 0.063 0.067
Year Mar 2003 0.180 Ended Mar 2004 0.222
* Estimated from July 2000 to September 2004.
102
Section E: Gas
Energy Data File January 2005
Table E.6: Summary of Gas Consumption by Sector Sectors
% of Total Gas Consumption
September Years
2002
2003
2004
2002
2003
2004
Industrial *
41.91
44.88
43.98
67.42
68.66
68.69
Commercial*
13.16
12.93
12.84
21.17
19.79
20.06
Residential
6.91
7.37
6.98
11.12
11.28
10.91
Domestic Transport**
0.18
0.18
0.22
0.29
0.28
0.35
62.16
65.37
64.02
100
100
100
TOTAL *
Gas Consumption Levels (PJ)
Excludes electricity generation but includes cogeneration.
** Estimated from July 2000 to September 2004.
Chart E.6: Gas Consumption by Sector
Table E.6 and Chart E.6 show gas consumption by sector from September years 2002 to 2004. Gas consumption for purposes other than petrochemical production and electricity generation (but including cogeneration) was 64.0 PJ for the year ended September 2004, an increase of 3.0% over two years from 62.2 PJ (see Table E.6).
Section E: Gas
Table E.6 shows that, in the year ended September 2004, gas consumption by domestic transport increased by 23% (from 0.18 PJ to 0.22 PJ), compared with the year ended September 2004. Gas consumption by the residential, industrial and commercial sectors fell by 5.3% (from 7.4 PJ to 7.0 PJ), 2.0% (from 44.9 PJ to 44.0 PJ) and 0.7% (from 12.9 PJ to 12.8 PJ) respectively, between 2003 and 2004.
103
E. Gas Figure E.1: Gas Flows for September Year 20041 By gross production:
FIELDS By net production:
5.0%
64.2%
16.5%
Mangahewa
Maui
Kapuni
Ngatoro2
5.4%
65.7%
15.3%
0.2%
Todd Taranaki 100%
Shell Explo 38.75% EPIL 20.00% Shell (Petro) 18.75% OMV 10.00% Todd Energy 6.25% TOPC 6.25%
Shell (Petro) 50% Todd Energy 50%
Operator: Shell Todd Oil Services
Operator: Shell Todd Oil Services
Operator: Shell Todd Oil Services
4.6%
McKee
4.8%
PRODUCERS
WHOLESALER
The Crown
0.3%
0.2%
7.3%
1.9%
Kaimiro
TAWN
Rimu3
0.1%
6.7%
1.8%
Greymouth 87% Southern 9% Greymouth Petro 4%
Greymouth 100%
Southern Petro 96.76% Swift Energy 3.24%
Swift Energy 100%
Operator: Greymouth
Operator: Greymouth
Operator: Swift Energy
Operator: Swift Energy
EGCL
EFNZL
Contact Energy
Shell (Petro) and Todd Energy
NGC
TRANSMITTERS
Genesis Power
(high pressure)
DISTRIBUTORS (low pressure)
RETAILERS
Powerco, Vector Genesis Energy4
NGC, Nova Gas, Wanganui Gas, Others5
Contact Energy
Major users supplied directly from the transmission system
CONSUMERS
By consumption: (calculated)
Users supplied from distribution systems
BHP NZ Steel Carter Holt Harvey Degussa Peroxide Fonterra Co-operative Todd Energy/ Kiwi Cogeneration NZ Refinery Company Southdown Cogeneration Tasman Pulp and Paper and some other companies
Methanex Other industry, commercial, residential, transport (as CNG)
43.4%
Chemical methanol manufacture
26.1%
Ballance AgriNutrients (Kapuni) Limited
Contact Energy Genesis Power
Ammonia/urea manufacture
Electricity generation
4.8%
25.7%
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 30 September 2004 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 and E Gas.
86
Section E: Gas
Energy Data File January 2005
Overview of New Zealand’s Gas Industry All statistics in this commentary apply to the year ended September 2004, and comparisons apply to that year relative to the year ended September 2003, unless otherwise specified. Overall comments are related to actual and proposed developments in the gas industry as at January 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. The rest is owned by a spread of public shareholders (33.95%). In July 2004, Australian company Origin Energy bought a 51.2% stake in Wellington-based Contact Energy for NZ$1.7 million or $5.67 per share from Californian-based Edison Mission Energy. Two petroleum mining permits were granted by Crown Minerals in 2004. On 8 October, 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 hydro-carbon reserves of 700 Bcf gas and 42.8 mmbbls of condensate. The Pohokura joint venture partners are Shell Exploration NZ Ltd (29.6673%), Shell (Petroleum Mining) Company Ltd (18.33%), Todd Pohokura Ltd (25.999%) and OMV NZ Ltd (25.999%). In September 2004, a 5.99 sq-km onshore petroleum mining permit for the production of gas and condensate was granted over the Kahili field. 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 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. Vector holds 16% of the Auckland gas market with 72,000 consumers. It has 200 km of fibre optic high-speed broadband voice and data communications in the Auckland and Wellington regions. (Source: Various issues of New Zealand Petroleum News – Ministry of Economic Development).
Developments Substantial development activities during 2004 included the granting of the Pohokura mining permit and progress on development plans for the Kupe oil Section E: Gas
and gas field. The drilling of production wells in the Pohokura field is scheduled to commence in mid2005, with initial production expected to be 50 PJ of gas and 3 mmbbls of condensate per annum. 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 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 313km onshore Maui pipeline from the Maui production station in south Taranaki to Huntly power station (1,000MW), 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 long-term contracts for the supply of Kupe, Mangahewa, McKee and Pohokura gas. The $520 million project is one of the largest infra-structure 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 News – Ministry of Economic Development).
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. 87
Energy Data File 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 first $750,000,000 of gross sales (offshore) for discoveries made during the period (was 20%). 3. APR of 15% for 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 at any time in the future. Costs incurred prior to the granting of a petroleum mining permit will 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. Taxation The so called “183 day rule” has been amended so 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. Other initiatives to promote exploration in New Zealand included the securing of Government backing for a $15 million seismic data acquisition project. In February 2005 a 4,200 km Crown-funded 2D seismic acquisition campaign commenced over the central and northern parts of the East Coast Basin. This survey will significantly increase understanding of the oil and gas potential of the East Coast Basin. The data acquired, and the results of subsequent geotechnical studies, will be released to industry free of charge to encourage further exploration in those areas. Figure E.1 presents a schematic of natural gas ownership and physical flows in New Zealand for the September year 2004, with proportions of gas produced by the different fields and consumed by major user/supplier categories.
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. 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 oil and gas (including condensate and naphtha). 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 81% of total production. They are both operated by Shell Todd Oil Services Limited. Other fields in production during the year to September 2004 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 Kaimiro, owned by Greymouth Petroleum Acquisition Company Limited. Together they provide the remaining 19% of total gas production. (See Chart E.1a.) As Chart E.1a illustrates, the Maui field was the major source of gas production, providing 64.2% of New Zealand’s gross gas production in the year ended 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 88
* Includes the Goldie well. ** Others include Mangahewa and Rimu fields.
Section E: Gas
Energy Data File January 2005
September 2004. The Kapuni field produced 16.5%, Tariki/Ahuroa 7.1%, Mangahewa 5.0%, McKee 4.6%, Rimu (including Kauri well) 1.9%, Ngatoro (including Goldie well) 0.3%, Kaimiro 0.2%, and Waihapa/Ngaere 0.2% of total gas production. The Moturoa field ceased producing gas in November 2001. Total New Zealand gas production in the year ended September 2004, excluding gas reinjected or flared, and LPG extracted was 155.4 PJ, a decline of 22% compared with 198.2 PJ in the year ended September 2003. This was mainly due to a significant decrease in production at Maui (27%). Other fields to display declining production over this period were Ngatoro (including Goldie well, 53% decline), Tariki/Ahuroa (31%), Kamiro (28%), Waihapa/Ngaere (10%), Mangahewa (2.6%) and Kapuni (2.3%). Gas reinjected for the September year 2004 was 0.29 PJ higher than the year ended September 2003 level of 0.01PJ. The Rimu and McKee fields increased their production by 107% and 14% respectively, compared with the year ended September 2003.
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 transmission system. NGC also operates extensive gas distribution and retail operations in the North Island Chart E.1b: Gas Use by Sector (September Years)
of New Zealand. There are five gas distributors: NGC Infrastructure, Nova Gas, Wanganui Gas, Vector and Powerco, and eight retailers: NGC (retails only to larger commercial and industrial customers), Nova Gas, Wanganui Gas, Contact Energy (gas wholesaler/ retailer), Genesis Energy, Mercury Energy, Bay of Plenty Electricity and E Gas.
Liquefied petroleum gas In addition to natural gas, the gas industry produced 8.6 PJ of liquefied petroleum gas (LPG) in the year ended September 2004, 9% lower than the year ended September 2003 level of 9.5 PJ. Of the 8.6 PJ of production, 0.7 PJ was exported and 7.6 PJ was used in New Zealand. In the year ended September 2004, 0.5 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.
Petrochemicals The petrochemicals sector used around 31% of New Zealand’s natural gas during the year ended September 2004 (in Methanex’s methanol plants at Motunui and Waitara, and the Ballance Agri-Nutrients (Kapuni) ammonia/urea plant) compared with 32% in the year ended September 2003. This was mainly due to a reduction in Methanex’s entitlements for Maui gas. Crude methanol is produced from natural gas and then distilled into high (“AA”) grade methanol. Methanex New Zealand produced 304,000 tonnes of methanol during the third quarter 2004 compared with 229,000 tonnes during the second quarter 2004. The company planned to produce approximately 250,000 tonnes during the fourth quarter 2004. Methanex has the potential to produce up to approximately 375,000 tonnes of methanol. Ballance Agri-Nutrients (Kapuni) Limited (previously Petrochem Limited) manufactures ammonia
Section E: Gas
89
Energy Data File January 2005
and urea from natural gas. The ammonia/urea plant uses Maui gas for fuel and a mixture of Maui and Kapuni LTS gas as a feedstock. Gas used in ammonia and urea production increased by 3.0% compared with the year ended September 2003.
Chart E.1c: Reticulated End Use by Sector
Electricity generation Gas used for electricity generation (including cogeneration) was about 41% of New Zealand’s natural gas produced during the year ended September 2004. Of the 41% of gas used for generation, 26% was used for electricity generation and 15% 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 41% and 9.9% to 38 PJ and 22 PJ respectively in the year ended September 2004, compared with the year ended September 2003 levels of 65 PJ and 24 PJ respectively.
Reticulated end use The remaining 28% of New Zealand’s gas use was reticulated throughout the North Island (by NGC) through a high-pressure 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 42.3 PJ of consumer energy (excluding cogeneration) reticulated in the year ended September 2004, 22.4 PJ (53.1%) was used by industry, 12.7 PJ (29.9%) by the commercial sector, 7.0 PJ (16.5%) by the residential sector and 0.2 PJ (0.5%) in transport (as CNG), as Chart E.1c illustrates.
90
Annual per capita end use of gas is 10.4 GJ (284 m3). Reticulated demand (observed, excluding cogeneration) increased 2.5% to 42.3 PJ from 41.3 PJ in the year ended September 2003. Chart E.4a (page 100) shows gas demand by direct major users (petrochemicals and electricity generation) and reticulated end use (industrial, commercial, residential and transport) from the September quarter 1974 to the September quarter 2004 and Chart E.4b compares gas demand share for September years 2003 and 2004. Gas demand by petrochemicals and electricity generation was about 85 PJ, 33% lower than the year ended September 2003 level of 126 PJ, while gas demand by reticulated end use (including cogeneration) increased by 2.1% to 64 PJ. Chart E.4b shows that in the year ended September 2004 gas demand by direct and reticulated users was 57% and 43% respectively, compared with 66% and 34% in the year ended September 2003. This was mainly due to a decline in gas consumption by Methanex and electricity generation.
Section E: Gas
Section E: Gas
Notes:
165.5
149.7
3
companies
Distribution Gas distribution
7.0
Residential
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.
12.7
22.4 Commercial
Other Industry Uses
Cogenerators
3
Observed 148.8
42.3
21.7
Genesis Power Limited
Contact Energy Limited
Includes the Goldie well.
Statistical Calculated difference 0.9 149.7 5
149.7
38.5
Electricity generation
Ballance Agri-Nutrients (Kapuni) Limited
Methanex New Zealand Limited
Includes the Kauri well.
Net production
Westech Energy
Todd Taranaki
Todd Petroleum and Shell
Swift Energy New Zealand Limited
Direct supply
46.3
2
Swift Energy New Zealand Limited
Shell Todd Oil Services Limited
New Zealand Oil and Gas Services Limited
Natural Gas Corporation of New Zealand Limited (NGC)
Direct supply
Non-energy use
USE
1
Gross production
Waihapa/Ngaere
Tariki/Ahuroa
Rimu 2
Ngatoro 1
McKee
Maui
Greymouth Petroleum Acquisition Company Limited
Maui Development Limited
Kapuni
Mangahewa
Transmission
Field operators
Gas flared and own use 6.5
LPG extracted 9.0
Gas reinjected 0.3
CONVEYANCE
Kaimiro
Fields
PRODUCTION
Petajoules (to approximate vertical scale)
Transport 0.2
BHP 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
Figure E.2: Gas Flow Summary for September Year 2004
Energy Data File January 2005
91
Energy Data File January 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
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
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
0.00 0.00 0.00 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
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
Notes: 1 For definition of terms used see Glossary, Section K, page 156. 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
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 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
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
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 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
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
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
Includes Goldie well. Includes Kauri well.
Chart E.1a1: Annual Gross Gas Production by Field (PJ) Others1 Waihapa/Ngaere/Piakau
2
McKee
Maui
Kapuni
Tariki/Ahuroa
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.
92
Section E: Gas
Energy Data File January 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
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
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
0.0 0.0 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
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
Notes: 1 For definition of terms used see Glossary, Section K, page 156. 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 67% of New Zealand’s total gas production in the calendar year 2003. Charts E.1a1 (page 92) and E.2a (page 95) show gross and net gas production respectively by field from 1970 to 2003. Gross gas production is total gas production after the first separation point. See Figure H.1, page 130. Net gas production is the difference between gross gas production and the amount of gas flared, gas reinjected, LPG extracted, own use and losses.
Section E: Gas
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 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
Mangahewa Ngatoro3 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 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
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 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
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 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.3 0.3 13.7 16.7 44.1
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
Includes Goldie well. Includes Kauri well.
Total New Zealand net gas production fell 24% to 174 PJ in 2003, compared with 230 PJ in the year ended December 2002. Overall, the amount of gas flared, gas reinjected, LPG extracted, own use and losses has generally been increasing since around 1978, but decreased by 17% to 16 PJ between 2002 and 2003. Of the total 16 PJ, 54% or 9 PJ relates to the Maui field, 25% or 4 PJ to the Kapuni field and the remaining 21% 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.
93
Energy Data File January 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
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
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
0.00 0.00 0.00 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
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
Notes: 1 For definition of terms used see Glossary, Section K, page 156. 2 Piakau has not produced gas since September 1999.
94
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 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
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 0.53 2.15 0.00 0.00 2.93 9.02 7.68
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 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
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 0.48 0.59 1.56
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
Includes Goldie well. Includes Kauri well.
Section E: Gas
Energy Data File January 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
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
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 24.86 24.74 23.31
0.00 0.00 0.00 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
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
0.00 0.00 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
Notes: 1 For definition of terms used see Glossary, Section K, page 156. 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
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
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
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.51 1.66
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
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
Section E: Gas
2
Piakau has not produced gas since September 1999.
95
Energy Data File January 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
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
150.1 286.0 393.3 463.6 384.9 446.8 1,299.6 2,081.3 1,971.9 861.6 338.5 298.5 342.2 390.2 371.4 386.5 480.8 415.6 424.9 425.7 456.1 718.1 706.5 701.4 660.3 692.1 734.1 770.0 752.0 808.6 916.4 936.7 927.4 865.8
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
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
Notes: 1 For definition of terms used see Glossary, Section K, page 156. 2 Piakau has not produced gas since September 1999. 3 All gas from the Moturoa field was used for own purposes.
96
Kaimiro/ Moturoa3 0.0 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
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 0.0 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
4
5
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 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
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
0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 12.7 40.9
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 6,252.5 5,938.2 4,486.9
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.
Section E: Gas
Energy Data File January 2005
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
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
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 32.75 30.58
0.00 0.00 0.00 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
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
Notes: 1 For definition of terms used see Glossary, Section K, page 156. 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
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
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
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
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.45 1.44
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 99.12 126.65 153.24 147.16 158.82 163.54 163.61 179.55 189.19 183.19 168.37 158.81 179.73 191.53 168.35 196.33 208.98 220.80 209.70 158.45
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.
97
Energy Data File January 2005
E.3 Gas Production (PJ) Chart E.3a: Quarterly Gas Production
Chart E.3b: Gas Production Percentages (September Years)
2004
98
2003
Section E: Gas
Energy Data File January 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
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
0.11 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
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
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
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
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
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
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 1999
Sep Dec
71.22 61.51
5.33 3.00
3.00 2.33
0.36 0.52
1.51 1.32
61.03 54.34
0.00 0.00
61.03 54.34
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
40.86 41.78 45.57
0.00 0.00 0.28
1.95 2.40 2.61
0.23 0.19 0.22
1.46 1.36 1.53
37.22 37.82 40.94
0.00 0.00 0.00
37.22 37.82 40.94
Year Sep 2003 209.14 Ended Sep 2004 165.54
0.01 0.29
9.75 8.96
1.16 0.86
5.84 5.70
192.38 149.74
0.00 0.00
192.38 149.74
* 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.)
99
Energy Data File January 2005
E.4 Gas Demand Chart E.4a: Quarterly Gas Demand
Chart E.4b: Gas Demand Share (September Years)
2004
100
2003
Section E: Gas
Energy Data File January 2005
Table E.4: Gas Demand (PJ) Calendar Year or Month
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
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
2.09 0.24 20.54 44.49 42.38 21.79 15.16 20.12 49.24 49.69 69.47 95.47 123.68 119.00 133.18 139.81 140.20 151.80 164.82 158.87 142.07 132.03 154.02 161.23 131.15 157.00 170.24 177.53 165.15 106.81
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 65.91
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
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
*
1999
Sep Dec
61.03 54.34
0.10 0.10
43.67 38.15
17.18 16.05
0.08 0.04
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
37.22 37.82 40.94
0.20 0.20 0.20
22.64 22.28 23.23
14.34 15.35 17.46
0.04 0.00 0.05
Year Ended
Sep 2003 Sep 2004
192.38 149.74
0.75 0.80
126.08 84.82
65.37 64.02
0.18 0.10
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.)
101
Energy Data File January 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
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 0.073 0.143 0.191 0.182 0.174
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
2001
Mar Jun Sep Dec
0.012 0.046 0.050 0.035
2003 Mar Jun Sep Dec
0.040 0.050 0.044 0.048
2004 Mar Jun Sep
0.044 0.063 0.067
Year Mar 2003 0.180 Ended Mar 2004 0.222
* Estimated from July 2000 to September 2004.
102
Section E: Gas
Energy Data File January 2005
Table E.6: Summary of Gas Consumption by Sector Sectors
% of Total Gas Consumption
September Years
2002
2003
2004
2002
2003
2004
Industrial *
41.91
44.88
43.98
67.42
68.66
68.69
Commercial*
13.16
12.93
12.84
21.17
19.79
20.06
Residential
6.91
7.37
6.98
11.12
11.28
10.91
Domestic Transport**
0.18
0.18
0.22
0.29
0.28
0.35
62.16
65.37
64.02
100
100
100
TOTAL *
Gas Consumption Levels (PJ)
Excludes electricity generation but includes cogeneration.
** Estimated from July 2000 to September 2004.
Chart E.6: Gas Consumption by Sector
Table E.6 and Chart E.6 show gas consumption by sector from September years 2002 to 2004. Gas consumption for purposes other than petrochemical production and electricity generation (but including cogeneration) was 64.0 PJ for the year ended September 2004, an increase of 3.0% over two years from 62.2 PJ (see Table E.6).
Section E: Gas
Table E.6 shows that, in the year ended September 2004, gas consumption by domestic transport increased by 23% (from 0.18 PJ to 0.22 PJ), compared with the year ended September 2004. Gas consumption by the residential, industrial and commercial sectors fell by 5.3% (from 7.4 PJ to 7.0 PJ), 2.0% (from 44.9 PJ to 44.0 PJ) and 0.7% (from 12.9 PJ to 12.8 PJ) respectively, between 2003 and 2004.
103
