BLACK ROCK MINING LIMITED — Capital/Financing Update 2012

May 28, 2012

==> picture [220 x 84] intentionally omitted <==

==> picture [224 x 46] intentionally omitted <==

29 May 2012

ASX Markets Announcements Australian Stock Exchange Limited 10[th] Floor, 20 Bond Street Sydney NSW 2000

Dear Sirs

BACKREEF-1 - OIL DISCOVERY

KEY POINTS:

• The Backreef Area Joint Venture has delineated a new highly productive reservoir within the hitherto non-commercially prospective Devonian aged Gumhole dolomite formation. This new oil reservoir play has the following calculated attractive reservoir characteristics:

•  permeability circa 750 millidarcy

•  porosity 17%

•  flow productivity > 1,000 bpd

•  thickness circa 6m and depth below surface 750m to 1,000m

• After the production test, ‘live oil’ samples were collected at surface from the Gumhole dolomite.

• Indications are that the Gumhole dolomite has potential commercial productivity. If a better sited well location up-dip from Backreef-1 can be delineated fully charged with oil, it may lead to a company-maker opportunity for Oil Basins Limited.

• Previously, the Backreef Area Joint venture has announced (pre-Test) that the significant undiscovered potential wholly within this new oil play zone has been defined, with a mapped oil in place (OIP) volume of between 45.6 to 117 MMbbls, with an expectation of 77.7 MMbbls and a mean estimate of 20.6 MMbbls prospective recoverable resources.

ASX & MEDIA ANNOUNCEMENT

Oil Basins Limited (ASX codes OBL , OBLOA and OBLOB or the Company) wishes to make the following announcement so as to keep the market fully informed.

The Company, as operator on behalf of the Backreef Joint Venture – OBL group net 80% and Green Rock Energy Limited (ASX code GRK ) group net 20%*, provides the following update on cased hole production testing operations at the Backreef-1 well.

Note: *Subject to stakeholder approvals and consents.

NEW OIL DISCOVERY WITHIN GUMHOLE FORMATION – BACKREEF-1

Production Test Results: Zone 1 Gumhole Formation

Following underbalanced perforation of the 4m interval 957m to 961mRT (Zone 1) observed surface pressure build-up was rapid to 364 psig and over 800m influx (approximately 12 bbls) was observed in test string on subsequent pressure gradient survey. The gradient survey indicated mostly water.

Evident initial flow rates were recorded in excess of 1000 bpd with permeability estimated at 750 millidarcy.

Downhole build-up was for a period of 2 hours and upon opening the tool downhole and although flow was indicated, no liquid flowed to surface.

After reverse circulation, the packer was unseated. Oil was observed at the surface of the well.

Two oil samples were collected before the packer was pulled. Additional oil was observed in the well after the packer was pulled out of hole and another sample was taken. Total oil collected amounted to circa 0.2 litres (Note - after packer tool was released and tubing string flushed).

All oil samples and formation water samples will be sent to the laboratory for further assay analysis. In addition, oil traces were observed in the reversed formation fluid. The collected oil appears to be very light and of similar qualities to the structurally down dip Blina Oil Field, some 7km to the west. The formation water included clean-up mud filtrate evidently lost during the drilling of this highly permeable zone.

Production Test Results: Zone 2 Yellow Drum Formation

Following underbalanced perforation of the upper 22m interval between 918m to 940mRT (Zone 2) observed surface pressure build-up was slow to 167.5 psig and initial test string influx was observed to 730mRT, upon subsequent pressure gradient survey. The gradient survey indicted a fresh water hydrostatic column. Evident permeability at between 0.1 to 10mD. Upon opening the downhole tool and after over 4 hours of swabbing operations, the height of the influx increased to 517mRT.

After reverse circulation, the packer was unseated but no traces of oil were observed at the surface. Water samples were taken for further laboratory analysis.

The well has now been suspended and the Australian Drilling Services Rig#2 was released at midday 27 May 2012.

Commenting on these results, OBL’s Executive Director and CEO Neil Doyle said:

“The Backreef Oil Discovery is the first new potentially significant oil find within Production Licence L6 since the discovery of the Blina Oil Field in 1981 by Canadian explorer Home Oil and the first potentially producible oil observed in the Gumhole dolomite formation.

The Gumhole dolomite has evident potential commercial productivity and if we can find better sited well locations up-dip from Backreef-1 with that Gumhole full of oil, it'll be a serious company-maker.

The oil discovery in the Gumhole completely justifies OBL’s faith in the application of the Company’s uniquely innovative approach to digitising and reprocessing vintage 2D seismic and the use of PSTM and PSDM techniques to this newly reprocessed vintage data”.

As previously stated by OBL to the ASX on 7 May 2012 (pre-Test), if the lower test in the Gumhole Formation recovers hydrocarbons, the result will be consistent with the Backreef Oil Pool contingent resource estimate determined by the earlier RPS Energy (RPS) independent resource evaluation report released on 24 November 2011.

RPS’s evaluation of the interval 917 to 994mRT within Backreef-1 found the major pay accumulation (6.8m) was centred between 956.7m to 963.5m MD and specifically cautioned that the potential

2

hydrocarbons are reservoired within layers of dolomitised carbonates with good indicated porosity but likely low permeability. Adopting (pre-Test) a relatively ‘low’ permeability analogue as evident from the nearby Blina Yellow Drum formation, RPS concluded for a 6m thick regionally extensive dolomitised reservoir the following:

==> picture [451 x 336] intentionally omitted <==

Figure 1

Oil Accumulations in the Vicinity of the Permit Area

==> picture [359 x 193] intentionally omitted <==

Figure 2

Commercial Hydrocarbon Accumulations, Western Fitzroy Trough, Canning Basin, source RPS

3

•  Reservoir quality would need to be demonstrated by a test at Backreef-1.

•  Oil production or oil samples will need to be obtained at Backreef-1.

•  The assumed permeable dolomitic reservoir would need to be demonstrated at Backreef-1.

•  Oil charge is expected to most likely occur from the southwest, and the leads are positioned updip from Blina.

•  Seal should be provided by intra-formational permeability changes, and ultimately by marls in the lower Laurel Formation.

•  The Kimberley Downs Embayment feature contained within of the Backreef Area could host a significant undiscovered potential Oil in Place (OIP) volume of between 45.6 to 117 MMbbls with an expectation of 77.7 MMbbls and a mean estimate of 20.6 MMbbls prospective recoverable resources.

•  The Resource estimates were in accordance with standard petroleum engineering techniques and using the March 2007 SPE/WPC/AAPG/SPEE Petroleum Resources Management System (PRMS).

A total of eight (8) Leads have been independently derived by RPS within the Kimberley Downs Embayment feature in the southern and south-eastern portions of the Company’s Backreef Area.

•  RPS also indicated that Backreef-1 was possibly sited within or very close to their observed oil water contact (which is clearly evident in the Backreef-1 production test result of Zone 1) and this distinct possibility was also canvassed “pre-Test” in the OBL ASX Release on 7 May that if this occurred the geological interpretation could be that Backreef-1 drilled the reservoirs just below the field oil/water contact, possibly within the transition zone between the oil column and the underlying water.

•  Successful recovery of oil from a future Backreef-1 well test will de-risk the charge and reservoir risk in the Backreef Lead, and reduce these risks in the other identified Leads. It would not de-risk the structural risk, as this would require additional seismic or well penetrations.

As previously stated (pre-Test) on 7 May 2012 interpretation could be that Backreef-1 drilled the reservoirs just below the field oil/water contact, possibly within the transition zone between the oil column and the underlying water.

OBL as operator of the Backreef Area, as permitted under the WA Petroleum and Geothermal Energy Resources Act 1967 (“the Act”) and on behalf of the Backreef Area Joint Venture (OBL group 80% / GRK group 20%), has sought to notify the Backreef Oil Discovery (under the meaning of the Act) to the WA Minister of Mines and Petroleum and, with the detailed mapping of the extent of the new oil play within the Gumhole already completed, will take steps to seek the immediate recognition of a Location over the entire Backreef Area as the first step towards the application for a new production licence.

Yours faithfully

==> picture [187 x 57] intentionally omitted <==

Neil Doyle SPE Director & CEO

4

DISCLAIMER

The technical information quoted has been complied and / or assessed by Mr Geoff Geary who is a professional geologist (Bachelor Science – Geology) with over 32 years standing and who is also a Member of Petroleum Exploration Society of Australia. Mr Geary has consented to the inclusion of the technical assessment in this ASX announcement. Investors are reminded at all times refer to the appropriate OBL ASX Releases and the information in the form and context in which they originally appear and in particular to the review the risk sections of the RPS expert report.

GLOSSARY & PETROLEUM UNITS

M Thousand MM Million B Billion bbl Barrel of crude oil (i.e. 159 litres) PJ Peta Joule (1,000 Tera Joules (TJ)) Bcf Billion cubic feet Tcf Trillion cubic feet (i.e. 1,000 Bcf) BOE6 Barrel of crude oil equivalent – commonly defined as 1 TJ equates to circa 158 BOE – approximately equivalent to 1 barrel of crude equating to 6,000 Bcf dry methane on an energy equivalent basis PSTM Pre-stack time migration – reprocessing method used with seismic. PSDM Pre-stack depth migration – reprocessing method used with seismic converting time into depth. AVO Amplitude versus Offset, enhancing statistical processing method used with 3D seismic. TWT Two-way time FMT Formation testing (pressure & sampling) tool TD Total depth GIP Gas in Place RT Relative to rotary turntable OWC Oil water contact STOIIP Stock tank oil in place (stabilised crude at atmospheric conditions) – also commonly referred to as Oil in Place (OIP) SwIrr Irreducible water saturation

5