Friday 19 May 2017 the Natural Resources Committee resolved to publish on its website the Minister’s response to the NRC’s Fracking report.
Mins response to fracking report.
Friday 19 May 2017 the Natural Resources Committee resolved to publish on its website the Minister’s response to the NRC’s Fracking report.
Mins response to fracking report.
Alan talks to the Liverpool Plains farmer about the Santos Narrabri gas project. 10/04/2017
Alan talks to the chemical engineer Tim Forcey from the Melbourne Energy Institute about methane emissions from coal seam gas. 10/04/2017 /
Download the document here facts regarding the gas in the SE 11th April 2017
On Friday 30th September many of our supporters took part in the Limestone Coast Protection Alliance Stay at Home Rally. If you were unable to take part on that day it is not too late to tell our South Australian government that you don’t want gasfields in the South East. Since Victoria announced a ban on […]
CHEMICALS ILLEGALLY INJECTED REPEATEDLY BY ENCANA IN 2004 INTO ROSEBUD’S DRINKING WATER AQUIFERS REMAIN SECRET, CONTRARY EVEN TO ALBERTA’S RULES OF COURT:
Encana still has not filed with Ernst cleaned up records for document exchange (which had a December 19, 2014 deadline ordered by Chief Justice Wittmann); chemicals Encana injected directly into Rosebud’s drinking water aquifers are also not yet filed with Ernst, even though required under the Court Rules, including all trade secrets.
Encana has also not disclosed the chemicals the company secretly injected into hundreds of other gas wells in various formations in fresh water zones around the community.
Follow the Jessica Ernst story here http://www.ernstversusencana.ca/the-lawsuit
Read Slickwater the book on Jessica’s story. https://www.newsouthbooks.com.au/books/slick-water_fracking-and-one-womans-fight-against-an-industry/
After energy giant Encana secretly fracked hundreds of gas wells around her home and her well water turned to a flammable broth, Jessica Ernst started asking questions. When she put forward evidence that Encana had violated laws by fracturing the community’s drinking water aquifer, Ernst was falsely tagged as a bomb-making terrorist and visited by the government’s anti-terrorism squad. Frightened but undaunted, she uncovered a startling history of liability, fraud, and intimidation, along with a willful denial of widespread groundwater contamination. Jessica Ernst’s remarkable story raises dramatic questions about the role of Big Oil in government, society’s obsession with rapidly depleting supplies of unconventional oil and gas, and the future of civil society.
Both Naomi Klein and Professor Tony Ingraffea have written forwards in the book.
Six LNG trains are expected to be set up from Curtis Island near Gladstone and are expected to produce 25million tonnes a year of LNG for export.
Queensland will be the world’s fourth largest LNG exporter by 2018.
The main companies involved in these LNG export trains are :
Queensland Gas Company (QGC)
Australia Pacific LNG (APLNG)
How can this all be taking place on Curtis Island which is a National Park and advertised as having unspoilt beaches on the Queensland National Park website!!
Maybe it is not the same place?? (Hopeful, but deluded! Editor)
The irreversible carving up of Curtis Island by Gas companies.
QGC operations involve the production of natural gas in more than 2,000 wells within the Surat Basin and Southern Queensland. The gas produced is transported via a 540km pipeline to the Curtis plant for conversion to liquefied natural gas (LNG) and export to overseas markets.
The Curtis LNG facility involved more than four years of development and construction work before it was operational.
QCLNG was the world’s first LNG project to use coal seam gas with its first production in December 2014.
Since then, the plant’s first train has exported 62 cargoes of LNG to overseas markets.
Commercial operations from its second train began in November 2015, after QGC assumed control of train 2 from Bechtel Australia, which originally built the facility.
QGC parent company is BG Group.
Santos has announced that GLNG train two has now begun producing liquefied natural gas (LNG) on Curtis Island in Queensland.
The announcement follows the first LNG production from train one in September 2015 and GLNG’s first LNG export cargo in October 2015.
Santos Managing Director and Chief Executive Officer Kevin Gallagher said the first LNG from train two was another milestone for GLNG and marked the successful delivery of the two-train project, which has already produced over two million tonnes of LNG and shipped 32 cargos.
“GLNG train two start-up adds to Santos’ LNG portfolio, which also includes the Darwin LNG and PNG LNG projects,” Mr Gallagher said.
Santos is the operator and has a 30 per cent interest in GLNG. The other co-venturers include PETRONAS (27.5 per cent), Total (27.5 per cent) and KOGAS (15 per cent).
Australia Pacific LNG has transitioned from projects to operations, after shipping its sixth LNG shipment in 2016 and has moved from projects to operations.
Australia Pacific LNG Chairman, Grant King, said, “Australia Pacific LNG, which recently commenced the export of LNG to its customers in Asia, actively demonstrates what can be achieved collectively when strong partnerships are forged.”
Australia Pacific LNG was formed in October 2008 and is a joint venture between Origin (37.5 per cent) ConocoPhillips (37.5 per cent) and Sinopec (25 per cent).
Doctors for the Environment Australia has presented their submission to the Senate Select Committee on Unconventional Gas and is calling for a moratorium on all new unconventional gas operations until health risk assessments of procedures and chemicals performed on an industry wide basis have been undertaken. DEA Submission available here.
“DEA is of the view that a national approach is essential to reduce the extensive risks associated with unconventional gas mining. The most (self-) evident reason for this is that sets of unconventional gas operations may take place in regions overlying, and therefore threatening, precious aquifers, aquifers that do not recognise state borders. DEA asks the Committee to be aware that medical and health research literature on unconventional gas is rapidly expanding. Much published research comes from the United States where an estimated 15 million people live within 1.6km of gas or oil wells.”
For more information go to DEA website here http://dea.org.au/resources/submissions
Do mining companies rehabilitate sites after they have removed the coal?
What are the state laws with regards to this, and more importantly what actually happens?
In Queensland there are the new Chain of Responsibility Laws, which have just today (26th May) for the first time been enacted requiring Linc Energy’s former CEO to decommission the sites waste water dams. We will watch the outcome of this with interest.
In April, a new report was released by Environmental Justice Australia’s Climate & Finance program which looked “at six methods that coal companies operating in Australia use to avoid, minimise or delay their rehabilitation obligations in New South Wales and Queensland.”
#1 CARE AND MAINTENANCE
#2 EXTRACT UNTIL CASH RESERVES RUN DRY
#3 DON’T REHABILITATE
#4 SELL TO AN UNKNOWN MINNOW
#6 INAPPROPRIATE DISCOUNTS
Read the full report here https://envirojustice.org.au/blog/dodging-clean-up-costs-six-tricks-coal-mining-companies-play
Leigh Creek Coal Gasification…really?
Renew Economy, excerpts
One company is proposing to use new technology to “gasify” the brown coal resource at Leigh Creek and use it for a large base load gas plant. Underground coal gasification has been banned in Queensland, but the South Australian government does not plan to follow that example.
“There is no need to politicise this process – the approval or otherwise of the proposed coal gasification project at Leigh Creek should be based on science,” Energy and Mineral Resources minister Tom Koutsantonis said in a prepared statement for RenewEconomy.
“Leigh Creek Energy will need to pass rigorous environmental impact assessments overseen by expert scientists if this project is to go ahead. We have a very effective regulatory framework in South Australia and the merits of the Leigh Creek Energy project will be assessed against that framework, not this decision in Queensland.”
(Seeing is not believing? Please note that the CEO of Leigh Creek Energy was a former Senior Manager with Linc Energy in Qld ! How does that make me feel safe? Ed.)
Information about petroleum companies with interest in the region.
Click here to download the document or scroll down to read it all here.
Links to companies websites
Petroleum Companies Update for Feb. Meeting
Cooper Energy Quarterly Report, Dec. 2015
Cooper Energy’s direct interests in the Gippsland Basin comprise: –
a 50% interest in VIC/RL3 which holds the Sole gas field assessed to contain Contingent Resources (2C)1 of 241 PJ of sales gas (refer ‘ Contingent Resource upgrade’ below);
a 65% interest and Operatorship of VIC/L26, VIC/L27 and VIC/L28 “BMG Joint Venture”) which contains the Manta gas and liquids resource. As reported in the June 2015 quarterly report, a business case study has confirmed the technical feasibility of a development of the Manta gas field, and that there is an economic opportunity for development of the field. Manta is assessed to contain Contingent Resources (2C)1 of 106PJ of sales gas and 3.2 million barrels of oil and condensate
a 50% interest in the Orbost gas plant, located onshore Victoria. The plant is currently in care and maintenance. Activities and outcomes in respect of these interests for the quarter are reported below.
Sole Gas Project The project encompassing the Sole field development, subsea tie-back and the Orbost Gas Plant upgrade continues as planned. The Define Phase, consisting of Front End Engineering and Design (FEED), together with parallel regulatory and commercial work-streams, was 31% complete at the end of December against planned progress of 32%. Plans have been put in place to accelerate progress against plan in the forthcoming quarter. Costs are running at 81% of budget and the project remains on schedule for a Final Investment Decision (FID) in the September quarter 2016. Negotiations for additional contracts to the O-I contract previously reported are in progress with other gas buyers and expected to result in the announcement of further gas sales commitments in the coming months.
Contingent Resource upgrade
Contingent Resource estimates for the Sole field were upgraded during the quarter following reinterpretation of the results of special core analysis of the reservoir section of the Sole-2 well in VIC/RL3. As announced to the ASX on 26 November 2015, the upgrade has resulted in the gross 2C resource for the field increasing from 211 PJ to 241 PJ of gas and Cooper Energy’s share of this increasing from 105 PJ to 121 PJ of sales gas.
Manta Gas Project Assessment of the optimal development plan and timeline for this project is advancing with ongoing work. 1 Contingent Resources assessed for the Sole and Manta fields were announced to the ASX on 26 November and 16 July 2015, respectively. Cooper Energy is not aware of any new information or data that materially affects the information provided in those releases and all material assumptions and technical parameters underpinning the assessment provided in the announcement continues to apply.
Gippsland Basin Gas Hub data room Gippsland Gas Hub Schematic The company opened a data room on the Gippsland Basin Gas Hub, which comprises the Sole and Manta Gas Projects and the Orbost Gas Plant. The data room has been opened to facilitate the involvement of other parties in the development of the hub for the purpose of optimising project funding and aligning commercial interests across the Gippsland gas assets. The data room has attracted engagement from a range of domestic and international parties. Alignment of interests in the Manta and Sole Gas Projects to enable development as a single integrated project offers significant economic benefits through the capture of cost and schedule synergies that yield a more valuable project than separate stand-alone developments. Other benefits include the opportunity for optimised exploration and development programs using the existing and proposed infrastructure. Engineering work to quantify the potential benefits from the existing Manta and Sole Gas Projects continues.
Managing Director’s comments
“The December quarter confirms the benefit of our focus on low cost production which can retain healthy margins notwithstanding the current low oil prices. We have a strong hedge book and have been successful with significant and ongoing reductions to capital and overhead expenditure. Our clear focus on containing costs whilst delivering key projects will be maintained. “Cooper Energy is set for an intense six months as we progress the development of the first of our cost competitive Gippsland Basin Gas Projects – ideally located to supply eastern Australia gas customers. “The Sole Gas Project can transform the company and is on schedule and below budget for FID in the September quarter of this year. Our decision to open a data room for the Gippsland Basin Gas Hub has generated interest from a range of domestic and international companies”.
T/49P – Offshore Otway (Beach 30%, 3D Oil 70% and operator) Detailed mapping of the Flanagan and Whalebone structures continued, with recommendations for future activity expected to be confirmed in Q3 FY16. These large structures were imaged in detail by the 974 km2 Flanagan 3D seismic survey acquired in the north of the block.
Prospectivity studies of the potential of the deeper Penola Trough are ongoing using results from the analysis of well and core data obtained from Jolly-1 and Bungaloo-1 in the Penola Trough, onshore Otway Basin, South Australia ( PEL 494 Cooper Energy 30%). Applications to suspend and extend PEPs 150, 168 and 171 for a further 12 months due to the ongoing moratorium on gas production are under review by the Victorian regulatory authority.
For Immediate Release – 12 January 2016
NEW CHIEF EXECUTIVE OFFICER
Beach Energy Ltd (ASX: BPT, “Beach”) is pleased to announce the appointment of Mr Matthew Kay as its new Chief Executive Officer, effective 17 July 2016 or such earlier date as is available and mutually agreed. Mr Kay holds tertiary qualifications in economics and a Master of Business Administration. He has over 25 years’ experience, and extensive senior leadership experience in the oil and gas industry. He is presently Executive General Manager, Strategy and Commercial at Oil Search Limited (“Oil Search”). Mr Kay joined Oil Search in 2014 after 12 years at Woodside Petroleum Limited and was before that at Santos Limited. Mr Kay’s extensive experience includes strategy and planning, upstream commercial, mergers and acquisitions, production planning and business improvement. Glenn Davis, the Chairman of Beach, said: “Mr Kay has developed an impressive depth of experience and leadership style across the Australian and international oil and gas industry for more than twenty five years. We are excited he is joining Beach in the position of Chief Executive Officer and look forward to his leadership driving execution of our corporate strategy, and particularly so after the successful completion of our merger with Drillsearch in the near future. Matthew’s background and experience are a great fit with our strategy.”
Beach Energy Monthly Drilling Report, Jan. 2016
AUSTRALIA – COOPER AND EROMANGA BASINS DEVELOPMENT South Australian Gas (Fixed Factor Area Joint Venture: Beach 20.21%, Santos 66.6% and operator, Origin 13.19%) A six‐well infill development drilling campaign was completed in the Moomba North Field, which aimed to develop booked reserves in the Toolachee, Daralingie and Patchawarra formations. A phased approach is being undertaken which may result in drilling up to 26 new wells in the area, six of which were drilled in 2014. Outcomes from the 2014 campaign were applied to the current campaign, including optimised well designs and improved well completions. During the month, the final two wells of the campaign, Moomba‐207 and Moomba‐208, intersected gas pay broadly in‐line with pre‐drill estimates. The completed drilling campaign proved successful, with all six wells cased and suspended as future producers.
EXPLORATION AND APPRAISAL Ex PEL 106 (Beach 50% and operator, Drillsearch 50%) A two‐well exploration program commenced on the western edge of the Patchawarra Trough, which aims to add reserves in the liquids rich gas play area. The first well of the campaign, Middleton East‐ 1, is located approximately 1.5 kilometres east of the producing Middleton‐1 well and targeted the Patchawarra Formation, with the Tirrawarra Sandstone providing a secondary target. Prospects were defined on the Irus 3D seismic survey, acquired in 2012 and reprocessed in 2013. Middleton East‐1 was cased and suspended following initial interpretation of wireline petrophysical and pressure data, which indicated six gas zones and net pay of 9.3 metres, including 4.9 metres intersected within the primary target zone. Extended production testing is expected to be undertaken at a later date to better assess flow rates and resource base.
Page 2 of 3 Monthly Drilling Report – January 2016 Ex PEL 91 (Beach 40% and operator, Drillsearch 60%) A two‐well oil appraisal program was completed in the Bauer Field to test southern and northern extensions of the field. Bauer‐25, the second well of the campaign, is located on the northern flank of the Bauer Field and is the northern‐most well in the field. The northern flank is a low relief area extending to the Bauer North‐1 discovery well, approximately 1.3 kilometres northeast of Bauer‐25. The well targeted the McKinlay Member and Namur Sandstone reservoirs, with the Birkhead Formation providing a secondary target. The well was cased and suspended as a future producer following intersection of a two metre net oil column in the Namur Sandstone and a 3.5 metre gross oil bearing interval in the overlaying McKinlay Member. Further evaluation of results will be undertaken to assess potential for follow‐up drilling.
No mention of Otway Basin.
JANUARY 12, 2016
Beach Energy has appointed oil and gas specialist Matthew Kay as its new chief executive, replacing Rob Cole, who left the struggling Australian energy company in September for personal reasons.
Mr Kay, currently the executive general manager of strategy and commercial at PNG-focused company Oil Search, will join Beach in July, or at an earlier date if the companies can agree.
Mr Kay takes over from acting chief executive Neil Gibbons and will receive a fixed annual salary of $900,000.
Beach recently swung to a full-year loss on impairments and low oil prices.
The company recorded a net loss of $514.1 million in the year to June 30, compared to last year’s profit of $101.78m.
BEACH Energy has appointed a new chief executive, however Matthew Kay, currently at Oil Search, will not start until as late as July 17.
Beach said Mr Kay was currently executive general manager, strategy and commercial, at Oil Search.
Before that he held various senior positions at Woodside Petroleum for 12 years and prior to that was at Santos.
Mr Kay will be paid $900,000 including superannuation.
He will receive up to 1.525 million performance rights on the first anniversary of starting with the company, and rights worth a maximum of $325,000 on the second anniversary.
If the company is taken over he will receive all of his rights, and if the company is taken over before he starts working at Beach he will be paid $1.54 million “in compensation for foregone incentives’’.
Beach Energy Media Release For immediate release – 3 February 2016, excerpts
CHANGES TO BOARD COMPOSITION
Beach Energy Limited (ASX: BPT, “Beach”) advises of the following changes to its Board of Directors, which are consistent with the terms of the proposed merger with Drillsearch Energy Limited (ASX: DLS, “Drillsearch”), as announced on 23 October 2015
. · Ms Belinda Robinson and Mr Robert Cole will resign from the Board, conditional upon successful implementation of the Drillsearch scheme of arrangement.
Quarterly Report for the period ended 31 December 2015, excerpts
Announcement of recommended merger of Beach and Drillsearch; merger approved by Drillsearch shareholders subsequent to quarter-end SUBSEQUENT EVENTS • Appointment of Mr Matthew Kay as Chief Executive Officer, effective 17 July 2016 or such earlier date as is available and mutually agreed
In order to maintain financial strength, Beach continues to review and adjust its capital expenditure program in response to declining oil prices. Within the constraints of existing contracts and committed expenditure, Beach has identified savings and reduced its FY16 capital expenditure guidance to $180 – $210 million (previously $240 – $270 million). The reduced range reflects savings achieved in H1 FY16 of approximately $20 million and further reductions and deferrals identified for H2 FY16 of up to $40 million. Subject to joint venture approval, the identified savings are expected through:
T/49P – Offshore Otway (Beach 30%, 3D Oil 70% and operator) Detailed mapping of the Flanagan and Whalebone structures continued, with recommendations for future activity expected to be confirmed in Q3 FY16.
Media Release Jan. 22
In order to maintain financial strength, Beach continues to review and adjust its capital expenditure program in response to declining oil prices. Within the constraints of existing contracts and committed expenditure, Beach has identified savings and reduced its FY16 capital expenditure guidance to $180 – $210 million (previously $240 – $270 million). The reduced range reflects savings achieved in H1 FY16 of approximately $20 million and further reductions and deferrals identified for H2 FY16 of up to $40 million
Acting Chief Executive Officer, Neil Gibbins, said “During these challenging times it is extremely pleasing to demonstrate Beach’s ability to live within its means and maintain financial strength. Despite lower oil prices, over the past six months we have held our net cash position relatively constant, secured increased debt financing facilities on improved terms, and identified up to $40 million of H2 FY16 savings and deferrals in our capital program. Operationally, we continue to perform well. Production levels were maintained during the second quarter of FY16, giving us greater confidence in our full year guidance, and recent infrastructure projects have delivered results better than expected.
PRL 1 (Wynn – 100%) PRL 2 (Limestone Ridge – 100%) PRL 13 (Beach 100%) PRL 32 (ex PEL 255 – 70%) PEL 186 (66.67%) PEL 494 (70%) PPL 62 (100%), PPL 168 (100%), PPL 202 (100%) GSRL 27 (100%)
PEP 150 (50%) PEP 168 (50%) PEP 171 (75%) PRL 1 (Buttress North – 10%) PPL 6, PPL 9 (10%),
Rawson Resources Quarterly Activity Report
Period Ending 31 Dec. 2015
Board and Management Changes
Rawson Resources was pleased to welcome Mr Michael McGowan to the Board as a Non-Executive Director on 01 October 2015. He has over 30 years’ experience in the oil and gas industry in various corporate and management roles with BP, Santos, Oil Search and more recently as the President and Chief Operating Officer of Eaglewood Energy Inc. Michael has extensive experience in Papua New Guinea and provides strength in the Company’s pursuit of acquiring multiple oil and gas opportunities within the country.
PRL 26 (Udacha) – Cooper Basin, South Australia (Beach Energy 15% – operator, Drillsearch 75%, Rawson 10%) Following the Udacha Joint Venture approval to put Udacha-1 into production, the Udacha-1 well underwent recompletion activities during the quarter. A new well head and tubing were installed to allow the well to be safely fracture stimulated ahead of being flow tested and tied back into production through the Middleton production facility. The Udacha gas field (Figure 1) was discovered in 2006 by the Udacha-1 well and is located approximately 5 kilometres northwest of the Middleton gas plant and 3 kilometres from the nearby Brownlow field. The block is located in the Cooper Basin, South Australia, and approximately 4 km west of the Brownlow-1 well and approximately 50 km north west of the Moomba Field.
SUBSEQUENT EVENT The Udacha Joint Venture successfully completed the fracture stimulation and flow test of the Udacha-1 well with flow test production commencing on 15 January 2016. Following five days of post fracture stimulation clean-up flow, a stabilised flow rate of 1.7 million standard cubic feet a day was achieved through a choke size of 24/64” at 650 psi over a 24 hour period. These results mean the Udacha Joint Venture can proceed with connecting the Udacha-1 well into the nearby Middleton production facility as planned. It is expected that production will start during the second quarter of 2016 and provide a long term revenue stream to Rawson and its joint venture partners.
Exploration Activities PEL 155 and PEL 154 – Otway Basin, South Australia (Otway Energy 100%) No operations or activities were undertaken during the quarter in PEL 154 and PEL155. Both licences remain in suspension until 03 July 2016. PEL155 is located in the Otway Basin, South Australia, approximately 10 km southeast of the Katnook Gas Fields, near the town of Nangwarry, South Australia. PEL154 comprises two separate blocks in the Otway Basin, South Australia. The eastern block is located approximately 16 kilometres west of Mount Gambier, while the western block is located approximately 18 kilometres southeast of Robe.
Otway Energy Pty Ltd is a 100% subsidiary of Rawson Resources Limited.
A memorandum entering the suspension of the Licence on the public record for the period 19 March 2014 to 18 September 2014 was made on 27 March 2014. This suspension was made under Section 90 (licence suspension) of the Act. A memorandum entering the suspension of the Licence on the public record for the period 04 July 2015 to 03 July 2016 was made on 20 February 2015. This suspension was made under Section 76A (suspension of licence conditions) of the Act. The Licence is now due to expire on 04 July 2018.
|Delisted following the completion of the compulsory acquisition process by Cooper Energy Limited (COE). Now Cooper Energy
Lakes Oil NL
Lakes Oil N.L.
For the three months ended
31 December 2015
The State parliamentary inquiry final report into onshore gas exploration was completed in December 2016 containing many recommendations. However, the Government is yet to respond to the findings of this inquiry.
All operational activities in Lakes’ Victorian permits continue to be stalled because of the onshore exploration moratorium.
Independent seismic attribute mapping of anomalous hydrocarbons in PEP 169 over the proposed Otway prospect provides better risk evaluation of reservoir, seal and fault integrity properties.
Lakes Oil NL and Controlled Entities ABN: 62 004 247 214 12 Directors’ Report (cont.) Exploration and Operational Summary Current Government position on onshore oil and gas exploration The Victorian State Government ban on all onshore oil and gas exploration activities has severely impacted on Lakes Oil’s ability to conduct exploration activities across the State. The Company has therefore been looking at other areas with more favourable regulatory conditions for exploration, as well as continuing to work up its portfolio in Victoria, in anticipation of the State lifting its onshore exploration ban. A further 12 months’ extension and suspension has been requested for each permit, for which application has been made. Lakes Oil’s new acreage acquisitions in Otway, Gippsland and Eromanga Basins Six new exploration areas were acquired during the year. These are : Onshore Otway Basin: permits PEP 167 and PEP 175 Nearshore Gippsland Basin permits: Vic/ P43(V) and Vic/ P44(V) Onshore Eromanga Basin (Queensland) permits: ATP 642P and ATP 662P
Community Consultations Lakes Oil has been actively involved in community consultation panel meetings held across western and eastern Victoria during the year. The purpose of these meetings has been to interface with community groups, independent consultants, local councils and other stakeholders and provide an open forum for discussion on any concerns relating to potential impacts on communities as a result of onshore gas exploration activities. The panels have been very productive as a starting point in getting an accurate message to the communities on the relevant issues and countering much of the misinformation that is presented as fact by particular interest groups. The outcomes from these panel meetings has now been compiled and submitted to the Victorian State Parliamentary inquiry in : “Report on community and stakeholder attitudes to onshore natural gas in Victoria. Prepared by the Independent Facilitator, The Primary Agency, 20 April 2015.” (Directors’ Report. 2015
PRL3 – Onshore Gippsland Basin (Lakes Oil, Operator, 100% interest) No operational activities took place in this permit during the period. Lakes Oil has been working to resolve the continued access issues to its chosen drill sites. The process of planning and engineering for two potential drilling sites had commenced, but because of the uncertainty of State bans on drilling, these plans have been indefinitely delayed. PEP166 – Onshore Gippsland Basin (Lakes Oil, Operator, 75% interest) (Armour Energy Ltd (Armour) 25% interest) No operational activities occurred in the permit in this period. Regional Mapping Regional mapping within the permit continued, evaluating the potential prospects to test additional Strzelecki and Rintouls Creek Formation tight gas and conventional plays. Without adequate and sufficient seismic data in the permit, mapping of intra-Strzelecki and base Strzelecki surfaces is extremely difficult. Re-interpretation of old coal bores, early wells and existing seismic data has been completed in the eastern part of the permit, where basement is indicated at around 3000 metres. Further mapping is continuing whilst the permit remains in a state of suspension due to the onshore exploration ban
Portland Energy Project: PEP 175 and PEP 167 Lakes Oil’s Strategic Plans for a major new onshore energy source for Victoria The Portland Energy Project in western Victoria is part of Lakes Oil’s new strategy to stimulate growth for the region and the State based on supply of newly discovered onshore natural gas resources that have been previously overlooked.
In view of the current moratorium on drilling for oil and gas in Victoria, Lakes has sought the support of the current Upper House inquiry into “Unconventional Gas in Victoria”, for the Government to allow it to drill two conventional proof of concept wells to confirm the presence of potentially recoverable onshore gas in the Otway Basin. Only then can it be sure of both the presence of moveable gas in the Eumeralla Formation and its potential for commerciality. Lakes Oil believes this gas can be extracted using conventional drilling methods, without needing hydraulic stimulation. · Lakes Oil’s permits (PEP 175 and PEP 167) are strategically located close to the deep port and smelter at Portland. · To further the case for potential economic development of a new major energy source, the onshore gas reserves in the region will be able to access existing pipelines that traverse the Lakes’ permits. · This will have favourable ramifications for the entire region and provide an opportunity to develop Portland as a major centre for employment. · Importantly, because of the shallow nature of the gas, the cost of recovery will be substantially less than for existing offshore development. Lakes Oil believes that this resource would be pivotal to providing affordable, clean energy to the State and will have a favourable impact on local industries. The Company is hopeful that it will obtain Government approval to drill two conventional “proof of concept” vertical wells to about 1500 metres to test the potential for gas to flow naturally from the Eumeralla Formation without the need for hydraulic fracturing. The locations of the wells are yet to be determined. The drilling specifications would use best practice guidelines and drill through the same on-shore geological formations in the Otway Basin as those being drilled with Government approval by Origin Energy.
Applications not yet granted
ELA 203/15 Application Coonalpyn Central 22/10/2015 700.0 squ. km. Flinders Mines Ltd 100%
ELA 204/15 Application Coonalpyn East 22/10/2015 934.0 squ. Km Flinders Mines Ltd 100%
ELA 205/15 Application Coonalpyn North 22/10/2015 877.0 squ.km. Flinders Mines Ltd 100%
ELA 206/15 Application Coonalpyn South 22/10/2015 863.0 squ.km. Flinders Mines Ltd 100%
ELA 207/15 Application Coonalpyn West 22/10/2015 670.0 squ.km. Flinders Mines Ltd 100%
SOUTH AUSTRALIA There were no exploration and evaluation activities carried out on the Company’s South Australian tenements during the December 2015 quarter.
Flinders Mines Ltd are looking for Nickel, Gold, Zinc, Copper and Lead. However, they are open to finding other minerals as well – hence looking for ‘minerals’. (From Anne Daw)
From Anne Daw.
Nuclear Waste Polls
The Advertiser’s http://www.adelaidenow.com.au/news/south-australia/nuclear-waste-dump-would-tip-445b-into-south-australian-economy-royal-commission-reveals/news-story/9c134d8b18020768b1e6c419d997982f