UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 6-K

Report of Foreign Private Issuer
 Pursuant to Rule 13a-16 or 15d-16 under the Securities Exchange Act of 1934

October 31, 2014

Commission File Number 000-55246

Sundance Energy Australia Limited

(Translation of registrant’s name into English)

633 17th Street, Suite 1950
Denver, CO  80202

(Address of principal executive office)

Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F.

Form 20-F x Form 40-F o

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(1): o

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(7): o

Indicate by check mark whether the registrant by furnishing the information contained in this Form is also thereby furnishing the information to the Commission pursuant to Rule 12g3-2(b) under the Securities Exchange Act of 1934.

Yes o No x

If “Yes” is marked, indicate below the file number assigned to the registrant in connection with Rule 12g3-2(b):  n/a

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

EXHIBIT INDEX

2

Exhibit 99.1

1

EAGLE FORD

The Company has increased its Eagle Ford acreage position to approximately 20,000 net acres.  The Company anticipates it will continue to add acreage through direct leasing in and around its core projects in the Eagle Ford.

During the quarter the Company produced 5,124 boepd, net of royalties, from its Eagle Ford assets.  The Company estimates lost production from downtime of approximately 1,000 boepd during the quarter, primarily as a result of shutting in wells to accommodate simultaneous operations on existing pads.

Table 1 below details initial production rates from the Company’s 2014 development program.  All wells were brought in to production with 14/64 chokes for production testing and then restricted to a 10/64 choke once producing into permanent production facilities.

Table 1: 2014 Eagle Ford initial production rates

(1) The Hoskins EFS 7H has 54 days of production included as its 60-day IP.  The rate will be updated in future releases.

2

MISSISSIPPIAN/WOODFORD

The Company has completed delineation of the Mississippian formation on its ~32,000 acre position and has identified approximately 100 gross (~80 net) operated well locations and 330 gross (60 net) non-operated well locations.  Future development will be optimized through pad development and zipper fraccing which serves to reduce cost per well and improve productivity per well (Figure 1).

Figure 1: Zipper fracced well results in Logan County

The Company’s focus on cost control has resulted in a 46% decrease in lease operating expense over the past 6 months (Figure 2).  Key factors include:

·                  Six strategically placed company operated SWDs provides cost effective development of leasehold pods;

·                  Electric in-place at 85% of our production facilities reducing the use of generators lowering costs;

·                  Aggressive switch from ESPs to rod pumps reducing downtime and costs associated with generators;

·                  Completion changes have allowed Sundance to eliminate jet pumps again reducing costs and downtime.

3

Figure 2: Lease operating cost per boe (trailing 3 month average)

The Company has drilled and completed 6 Woodford appraisal wells in 2014 that are producing commercial quantities of hydrocarbons.  Table 2 shows initial production rates from those drilled and completed in 2014.

Table 2: Woodford appraisal well production results

For more information, please contact:

4

About Sundance Energy Australia Limited

Sundance Energy Australia Limited (ASX: SEA) is an Adelaide-based, independent energy exploration company, with a wholly owned US subsidiary, Sundance Energy Inc., located in Denver, Colorado, USA.

The Company is focused on the acquisition and development of large, repeatable oil and natural gas resource plays in North America. Current activities are focused in the Eagle Ford, Williston, Denver-Julesburg and Anadarko Basins.

A comprehensive overview of the Company can be found on Sundance’s website at www.sundanceenergy.net.

Disclaimer

This announcement is for publication in Australia and not for release in the United States. This announcement does not constitute an offer to sell, or a solicitation of an offer to buy, any securities in the United States or any other country. Any securities described in this announcement have not been registered under the US Securities Act of 1933 and may not be offered or sold in the United States absent registration or an exemption from registration under the US Securities Act and applicable US state securities laws.

Reserves

This presentation contains information on Sundance Energy’s reserves and resources which has been reviewed by David Ramsden-Wood, Professional Engineer, who is licensed in Alberta Canada and is qualified in accordance with ASX Listing Rule 5.11.  Mr. Ramsden-Wood, VP of Reservoir Engineering and Business Development, has consented to the inclusion of this information in the form and context in which it appears.

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Exhibit 99.2

Sundance Energy Australia Limited

32 Beulah Road, Norwood. South Australia. 5067  ACN 112 202 883

Telephone:  +61 8 8363 0388  Facsimile: +61 8 8132 0766  www.sundanceenergy.com.au

Activities Report for the Quarter Ended 30 September 2014

Highlights

All amounts shown in this report are unaudited.

1

Operating Results

NOTE: Production & Revenue figures are presented net of royalties.

(1) Prior to the fourth quarter of 2013, the Company did not report flared gas.

Revenue for the quarter increased $17.8 million, or 61.9 percent, to $46.5 million compared to the same period in prior year.  Increased production of 3,050 Boe/d from the Company’s successful multi-rig drilling program contributed $21.8 million and improved natural gas and NGL pricing contributed $1.0 million to the increase in revenue.  Offsetting these increases in revenue was a $10.89 per barrel decrease in oil price which negatively impacted revenue by $5.0 million.

For the current quarter, the Company realised $93.08 per Bbl (10.5 percent decrease compared to the same quarter in 2013) of oil and $3.27 per Mcf (81.7 percent increase compared to the same quarter in 2013) of natural gas, net of transportation and marketing fees.

For the quarter ended 30 September 2014, the Company produced an average of 7,035 Boe/d, which includes 378 Boe/d of flared gas.  Gas pipeline construction for the Company’s Q-Ballard, Q-Kiel, Dusek and Lange wells in the Eagle Ford was completed in September 2014 and the Company hooked up 9 gross wells to the gas gathering system, which is expected to significantly decrease flared gas volumes.

All amounts shown in this report are unaudited.

2

Excluding flared gas, Sundance produced an average of 6,657 Boe/d during the quarter, up 84.6 percent from 3,607 Boe/d in the same period in prior year.

For the nine months ended 30 September 2014, Sundance produced an average of 5,861 Boe/d, which includes 407 Boe/d of flared gas, up 137.9 percent from 2,464 Boe/d in the same period in prior year. Excluding flared gas, Sundance produced an average of 5,454 Boe/d for the nine months ended 30 September 2014, up 121.3 percent from 2,464 Boe/d in the same period in prior year.

During the nine-months ended 30 September 2014, the Company’s oil, natural gas and NGL sales revenue increased $60.7 million (110.1 percent) to $115.9 million from $55.2 million in the comparable period in the prior year.  Increased production of 2,990 Boe/d contributed $62.9 million and improved natural gas and NGL pricing contributed $2.0 million to the increase in revenue.  Offsetting these increases in revenue was a $3.81 per barrel decrease in oil price which negatively impacted revenue by $4.2 million.

Lease operating expenses (LOE)

In early 2014, the Company implemented several changes in its field operations that have resulted in a reduction of $6.82, or 53.4 percent, to $5.96 LOE per Boe for the quarter ended 30 September 2014 compared to the same period in 2013.  For the nine-months ended 30 September 2014, LOE per Boe decreased by $3.61, or 34.7 percent, to $6.80 as compared to $10.41 for the same period in 2013.

Production tax expense

As a result of the Company’s continued production shift out of North Dakota and Colorado (higher production tax rate jurisdictions) and into Texas and Oklahoma (lower production tax rate jurisdictions), its average production tax expense as a percentage of revenue has decreased 2.4 percentage points (29.4 relative percent) from 8.1 percent in 2013, to 5.7 percent for the quarter ended 30 September 2014.  For the nine-months ended 30 September 2014, production tax expenses as a percentage of revenue has decreased 2.1 percentage points (26.2 relative percent) from 7.8 percent in 2013 to 5.7 percent in 2014.

All amounts shown in this report are unaudited.

3

General and administrative costs (G&A)

G&A per Boe decreased 45.9 percent to $7.04 per Boe for the quarter ended 30 September 2014 compared to the same period in 2013 as the Company captured economies of scale in its fixed overhead cost structure from increased production levels.  For the nine-months ended 30 September 2014, G&A per Boe decreased to $9.12, or 52.0 percent, as compared to the same period in 2013.

Adjusted EBITDAX

Adjusted EBITDAX is defined as earnings before interest expense, income taxes, depreciation, depletion and amortisation, property impairments, gain/(loss) on sale of non-current assets, exploration expense, share-based compensation and gains and losses on commodity hedging, net of settlements of commodity hedging.

The Company’s topline revenue growth and reduced operating expenses on a per unit basis translated to growth in Adjusted EBITDAX, with the Company generating $36.0 million in Adjusted EBITDAX, or 77.6 percent of revenue, for the quarter ended 30 September 2014 compared to $17.7 million, or 61.8 percent of revenue, for the same period in 2013.  For the nine-months ended 30 September 2014, Adjusted EBITDAX was $86.1 million, or 74.3 percent of revenue, compared to $32.1 million, or 58.2 percent of revenue, from the same period in 2013.

The Company’s Adjusted EBITDAX growth relative to its revenue growth for the three months ended 30 September 2014 was 103.0 percent compared to the same period in 2013.  Meaning, for every $1.00 that revenue increased for the period, the Company’s Adjusted EBITDAX increased $1.03 due to operating cost control measures.  For the nine months ended 30 September 2014, Adjusted EBITDAX growth relative to its revenue growth was 89.0 percent compared to the same period in 2013 (for every $1.00 that revenue increased, Adjusted EBITDAX increased $0.89).

All amounts shown in this report are unaudited.

4

The Company utilises derivative contracts to manage and protect against commodity price risk.  As at 30 September 2014, the following derivative contracts were in place:

Exploration & Development

The Company’s exploration and development activities are focused in the Eagle Ford formation (Texas) and the Mississippian/Woodford formations in the Greater Anadarko Basin (Oklahoma).  Costs incurred for exploration, development and production expenditures in the quarter ended 30 September 2014 totaled $84.5 million.  This investment resulted in the addition of 26 gross (17.2 net) producing wells with an additional 29 gross (19.1 net) wells in progress as at 30 September 2014.  Excluding capitalised overhead, interest and asset reclamation obligations of $6.3 million, year-to-date development and production costs through 30 September 2014 were $234.2 million.  We anticipate fourth quarter development capital expenditures of $65 to $70 million, bringing full year development capital expenditures of $299 to $304 million, which is $9 to $14 million (approximately 3.1 percent) higher than the high-end of the $270 to $290 million range previous guidance due to faster than expected drilling.

In late 2013, the Company shifted to pad drilling in the Eagle Ford.  All wells on the pads are planned to be drilled and completed prior to commencing production.  The Company added a dedicated frac crew for completion operations in the Eagle Ford in the second quarter.  During the third quarter of 2014, the Company completed 14 gross (10.5 net) wells in the Eagle Ford with all of those wells beginning production.  The Company expects initial production from 10-13 gross Sundance operated Eagle Ford wells in the fourth quarter of 2014.

The Company’s development activities for the quarter ended 30 September 2014 are summarised below:

All amounts shown in this report are unaudited.

5

(1) DJ Basin assets were disposed in July

(2) Williston assets were disposed in July

All amounts shown in this report are unaudited.

6

The Company’s capital expenditures for the quarter ended 30 September 2014 are summarised below:

(1) Represents total costs incurred, not cash paid, for capital expenditures during the quarter.  Amounts exclude $35 million of costs incurred from acquisitions during 2014.

Eagle Ford

During the quarter, 14 gross (10.5 net) Eagle Ford wells began production.  As at 30 September 2014, the Company had 17 gross (13.9 net) wells drilling, waiting on completion, fraccing or production testing.  Eagle Ford contributed 5,124 Boe/d (72.8 percent) of total production during the quarter compared to 1,859 Boe/d (51.5 percent) of total Boe/d produced during the same period of 2013.  The Company operated 98.6 percent of its Eagle Ford production for the quarter.

In July, Sundance completed the acquisition of approximately 5,700 net Eagle Ford acres plus an additional 5,400 net Georgetown acres in Dimmit County, South Texas, for approximately $35 million.  Sundance also has the option, at its sole discretion, to acquire the Seller’s remaining working interests for an additional $45 million.

Greater Anadarko Basin

During the quarter, 12 gross (6.7 net) Mississippian and Woodford wells had initial production; of which 7 gross (5.8 net) were Sundance-operated.  As at 30 September 2014, Sundance had 12 gross (5.2 net) wells drilling, waiting on completion, fraccing or production testing.  Anadarko contributed 1,574 Boe/d (22.4 percent) of total production during the quarter compared to 541 Boe/d (15.0 percent) of total Boe/d produced during the same period of 2013.  The Company operated 77.5 percent of its Anadarko production for the quarter.

Denver-Julesburg Basin

In July, Sundance divested of its Denver-Julesburg Basin assets for approximately $113.4 million.

Williston Basin

The Company’s only remaining Bakken asset was sold in July 2014 for approximately $14 million, which included $10 million in cash and approximately $4 million in settlement of a net liability due to the buyer.

All amounts shown in this report are unaudited.

7

As at 30 September 2014, the Company had approximately $50.9 million of cash and cash equivalents and $65.0 million of undrawn borrowing capacity under its reserve based lending facility. A redetermination of the Company’s borrowing base is underway with its bank syndicate, which is expected to increase availability under the facility.

Yours sincerely,

Sundance Energy Australia Limited

Eric McCrady

Managing Director and Chief Executive Officer

For further advice on this release, please contact:

About Sundance Energy Australia Limited

Sundance Energy Australia Ltd (ASX: SEA) is an Adelaide-based, independent energy exploration Company, with a wholly owned US subsidiary, Sundance Energy, Inc., located in Colorado, USA. The Company is developing projects in the US where it is primarily focused on large, repeatable resource plays where it develops and produces oil and natural gas reserves from unconventional formations.

A comprehensive overview of the Company can be found on the Company’s website at www.sundanceenergy.com.au.

All amounts shown in this report are unaudited.

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Appendix 5B

Mining exploration entity quarterly report

Rule 5.3

Appendix 5B

Mining exploration entity quarterly report

Introduced 01/07/96  Origin Appendix 8  Amended 01/07/97, 01/07/98, 30/09/01, 01/06/10, 17/12/10

Name of entity

Sundance Energy Australia Limited

Consolidated statement of cash flows

+ See chapter 19 for defined terms.

17/12/2010

9

(1)         During the second quarter of 2014, the Company paid approximately $4.3 million related to the post-closing settlement of the Phoenix disposition.

Payments to directors of the entity and associates of the directors

Payments to related entities of the entity and associates of the related entities

Non-cash financing and investing activities

10

Financing facilities available

Add notes as necessary for an understanding of the position.

Estimated cash outflows for next quarter

Reconciliation of cash

Reconciliation of cash at the end of the quarter (as shown in the consolidated statement of cash flows) to the related items in the accounts is as follows.

11

Changes in interests in mining tenements