Raging River Exploration Inc. Announces Second Quarter Operating and Financial Results and Increased 2014 Guidance

CALGARY, ALBERTA--(Marketwired - Aug. 12, 2014) - Raging River Exploration Inc. (the "Company" or "Raging River") (TSX:RRX) announces its operating and financial results for the three and six months ended June 30, 2014. Selected financial and operational information is outlined below and should be read in conjunction with the unaudited interim financial statements and the related management discussion and analysis ("MD&A"). These filings will be available at www.sedar.com and the Company's website at www.rrexploration.com.

Financial and Operating Highlights

			Three months ended June 30,				Percent Change		Six months ended June 30,				Percent Change
			2014		2013				2014		2013
Financial (thousands of dollars except share data)
Petroleum and natural gas revenue			88,931		36,264		145		169,638		69,415		144
Funds from operations (1)			56,283		25,527		120		106,095		48,910		117
	Per share - basic		0.32		0.16		100		0.60		0.31		94
		- diluted	0.30		0.15		100		0.57		0.30		90
Net earnings			30,238		8,810		243		54,597		15,052		263
	Per share - basic		0.17		0.06		183		0.31		0.10		210
		- diluted	0.16		0.05		220		0.29		0.09		222
Development capital expenditures			27,789		9,536		191		99,807		47,143		112
Property and corporate acquisitions			-		1,047		(100	)	-		1,047		(100	)
Total capital expenditures			27,789		10,583		163		99,807		48,190		107
Net debt(3)			89,333		14,437		519		89,333		14,437		519
Shareholders' equity			437,159		273,703		60		437,159		273,703		60
Weighted average shares (thousands)
	Basic		179,438		156,757		14		177,460		156,757		13
	Diluted		188,002		166,546		13		185,523		165,777		12
Shares outstanding, end of period (thousands)
	Basic		179,890		156,757		15		179,890		156,757		15
	Diluted		195,104		180,829		8		195,104		180,829		8
Operating (6:1 boe conversion)
Average daily production
	Crude oil and NGLs (bbls/d)		9,500		4,387		117		9,463		4,420		114
	Natural gas (mcf/d)		2,765		1,401		97		2,518		993		154
	Barrels of oil equivalent (2)(boe/d)		9,960		4,620		116		9,883		4,585		116
Netbacks
	Operating
		Oil and gas sales(3)	98.11		86.26		14		94.83		83.64		13
		Royalties	(9.63	)	(7.46	)	29		(8.96	)	(7.21	)	24
		Operating expenses	(11.99	)	(12.78	)	(6	)	(12.24	)	(12.72	)	(4	)
		Transportation expenses	(1.99	)	(2.25	)	(12	)	(2.00	)	(2.23	)	(10	)
Field netback			74.50		63.77		17		71.63		61.48		17
		Realized loss on derivatives	(2.34	)	(0.49	)	378		(2.10	)	(0.18	)	1,067
	Operating netback ($/boe)		72.16		63.28		14		69.53		61.30		13
		General and administrative expense	(1.43	)	(1.95	)	(27	)	(1.45	)	(1.92	)	(24	)
		Financial charges	(1.19	)	(0.61	)	95		(1.11	)	(0.46	)	141
		Current taxes	(7.45	)	-		100		(7.66	)	-		100
Funds flow netback			62.09		60.72		2		59.31		58.92		1
Wells drilled
	Gross		23		5		360		98		50		96
	Net		22.0		4		450		87.6		42.2		108
	Success(4)		96	%	100	%	(5	)	95	%	100	%	(5	)

(1)	See "Non-IFRS Measures"
(2)	Boe conversion ratio for natural gas of 1 Boe: 6 Mcf has been used, which is based on an energy equivalency conversion method primarily applicable at the burner tip and does not necessarily represent a value equivalency at the wellhead. As the value ratio between natural gas and crude oil based on the current prices of natural gas and crude oil is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
(3)	Excludes unrealized risk management contracts.
(4)	100% of wells drilled in the second quarter of 2014 were cased and completed however 1 (1.0 net) wells was junked and abandoned. Geological indications on this well were positive and it will be re-drilled at a later date.

SECOND QUARTER 2014 HIGHLIGHTS

• Achieved record average production of 9,960 boe/d (95% oil), an increase of 2% from the first quarter of 2014 and an increase of 116% over the comparable period in 2013.
• Increased average production guidance to 10,300 boe/d from 9,800 boe/d and increased exit guidance to 12,100 boe/d from 11,700 boe/d.
• Attained record corporate funds flow from operations of $56.3 million ($0.32/share basic), an increase of 13% from the first quarter 2014 funds flow from operations of $49.8 million.
• Achieved record operating netbacks of $72.16/boe and very strong funds flow netbacks of $62.09/boe.
• Achieved record earnings of $30.2 million ($0.17/share basic) or $33.36/boe.
• Attained industry leading general and administrative costs of $1.43/boe.
• Achieved a 6% reduction in operating costs to $11.99/boe from the comparable period in 2013.
• The Company spent $27.8 million on capital expenditures including $27.3 million on development activities in addition to $0.4 million on land. A total of 23 (22.0 net) horizontal Viking oil wells were drilled and completed, testing 14 (13.5 net) new sections.
• Decreased net debt to $89.3 million representing 0.4 times debt to the second quarter annualized cash flow.

CONSOLIDATION TRANSACTIONS

Raging River has completed a sequence of transactions of Viking light oil assets primarily in our core area of Forgan (the "Consolidation Transactions"). The details of the transactions are as follows:

Total cash consideration:	$4.5 million
Drilling commitment:	5 wells by March 31, 2015
Land prospective for Viking oil:	12,000 net acres
Total risked drilling locations:	125 net horizontal wells
Production:	30 bbls/d (100% light oil)

INCREASED 2014 GUIDANCE

Inclusive of the aforementioned Consolidation Transactions, the board of directors has approved an increase in our capital budget to $260 million. The continued success of our delineation efforts combined with the increased capital budget have resulted in our third guidance increase of 2014, as follows:

• Average production increasing 2% to 10,500 boe/d from 10,300 boe/d.
• Exit production guidance increasing 3% to 12,500 boe/d from 12,100 boe/d.

Balance sheet strength will be maintained with net debt to annualized fourth quarter cashflow now expected to be approximately 0.5 times.

OUTLOOK AND OPERATIONS UPDATE

A total of 23 (22 net) wells testing 14 (13.5 net) undrilled sections were drilled in the second quarter. In all cases the geological data was compelling with all wells cased and completed. However, during completion operations, one well encountered a casing collapse which resulted in the abandoning of the well. Given the geological success of this well, it will be re-drilled later in the year.

Third quarter to date, 30 (23.9 net) additional wells have been successfully drilled, testing 10 (8.3 net) new sections. These wells are currently in various stages of completion. The third quarter of 2014 is expected to be our busiest quarter on record with 75 to 80 net wells expected to be drilled during the quarter.

Area Highlights:

• Forgan:
  • 6 wells drilled in the first quarter of 2014 have all been on production greater than 120 days with average rates of 40 bbls/d of oil.
  • 18 (16.2 net) wells have been drilled since June with 10.9 net wells testing previously undrilled sections. These wells have successfully extended the boundaries of the proven economic edges of the play.
  • Added 15 net sections of land through the Consolidation Transactions previously mentioned.
• Beadle:
  • 19 (17.8 net) wells drilled since June 2014 at 100% success.
  • 9 (7.8 net) of the wells drilled since June have tested previously undrilled sections. Early time production results from these wells have been favorable again extending the boundaries of the proven economic edges of the play.
  • The 39 wells placed on production in the area in 2014 have shown 150 day average oil rates of 37 bbls/d which is consistent with the 30 wells drilled in the area in 2013.
• Plato:
  • 16 wells placed on production in the area in the first quarter of 2014 have shown six month average oil rates of 50 bbls/d, which are the strongest wells drilled in the area to date.

Raging River continues to refine completion techniques through pumping additional fracture stages and increased tonnage per well. The increased fracture stages and tonnages have increased our overall per well costs from historical averages of $875-900 thousand per well to approximately $910 thousand per well. The incremental cost of the larger completions are showing positive initial results with shallower decline profiles on our wells.

PRODUCTION UPDATE

Production levels moderated through breakup to lows of 9,600 boe/d and have now began to increase concurrent with capital activities with current production in excess of 10,500 boe/d.

EXECUTIVE APPOINTMENT

The board of directors is pleased to announce the appointment of Mr. Scott Rideout to the role of Vice President Land. Mr. Rideout spent the last 4 years with Surge Energy Inc., most recently as Manager Business Development and Land, and has 8 years of prior industry experience.

Raging River's experienced management team remains committed to operational and executional excellence to continue delivering per share value growth to our shareholders while maintaining balance sheet strength.

Additional corporate information can be found in our corporate presentation on our website at www.rrexploration.com

FORWARD LOOKING STATEMENTS: This press release contains forward-looking statements. More particularly, this press release contains statements concerning increased average production guidance for 2014, anticipated exit production for 2014, Raging River's expected net debt to fourth quarter annualized cash flow, expectation that the Company will maintain balance sheet strength, Raging River's drilling plans and timing thereof, the Company's expected 2014 capital budget, Raging River's intention to re-drill a well where the casing collapsed during completion operations and Raging River's growth strategy and anticipated growth plans for 2014. In addition, the use of any of the words "guidance", "initial, "scheduled", "can", "will", "prior to", "estimate", "anticipate", "believe", "potential", "should", "unaudited", "forecast", "future", "continue", "may", "expect", "project", and similar expressions are intended to identify forward-looking statements. The forward-looking statements contained herein are based on certain key expectations and assumptions made by the Company, including but not limited to expectations and assumptions concerning the success of optimization and efficiency improvement projects, the availability of capital, current legislation, receipt of required regulatory approval, the success of future drilling and development activities, the performance of existing wells, the performance of new wells, Raging River's growth strategy, general economic conditions, availability of required equipment and services and prevailing commodity prices. Although the Company believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because the Company can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; as the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses, and health, safety and environmental risks), commodity price and exchange rate fluctuations, changes in legislation affecting the oil and gas industry and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. Refer to Raging River's most recent Annual Information Form dated March 17, 2014 for the year ended December 31, 2013, on Sedar at www.sedar.com, and the risk factors contained therein.

The forward-looking statements contained in this press release are made as of the date hereof and the Company undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.

ADVISORY ON PRODUCTION INFORMATION: Unless otherwise indicated herein, all production information presented herein has presented on a gross basis, which is the Company's working interest prior to deduction of royalties and without including any royalty interests.

NON-IFRS MEASURES: This document contains the terms "funds from operations" (or "cash flow"), "net debt", "field netback", "operating netback" and "funds flow netback", which do not have a standardized meaning prescribed by International Financial Reporting Standards ("IFRS") and therefore may not be comparable with the calculation of similar measures by other companies. Management uses funds from operations to analyze operating performance and leverage. Management believes "net debt" is a useful supplemental measure of the total amount of current and long-term debt of the Company. Mark-to-market risk management contracts are excluded from the net debt calculation. Management believes "field netback", "operating netback" and "funds flow netback" are useful supplemental measures of firstly, the amount of revenues received after royalties and operating and transportation costs, secondly, the amount of revenues received after royalties, operating, transportation costs and realized gain (loss) on derivatives, and thirdly, the amount of revenues received after royalties, operating, transportation costs, realized gain (loss) on derivatives, general and administrative costs, financial charges, current taxes and asset retirement obligations. Additional information relating to certain of these non-IFRS measures, including the reconciliation between funds from operations and cash flow from operating activities, can be found in the MD&A.

BARRELS OF OIL EQUIVALENT: The term "boe" or barrels of oil equivalent may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent (6 Mcf: 1 bbl) is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Additionally, given that the value ratio based on the current price of crude oil, as compared to natural gas, is significantly different from the energy equivalency of 6:1; utilizing a conversion ratio of 6:1 may be misleading as an indication of value.

INITIAL PRODUCTION RATES: Any references in this press release to initial production rates are useful in confirming the presence of hydrocarbons, however, such rates are not determinative of the rates at which such wells will continue production and decline thereafter. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production for the Company.