Whitecap Resources Inc. Announces 66% Increase to 2014 Year End Reserves and Provides 2015 Revised Guidance

CALGARY, Jan. 27, 2015 /CNW/ - Whitecap Resources Inc. ("Whitecap" or the "Company") (TSX: WCP) is pleased to report record production in the fourth quarter of 2014 of 37,600 boe/d (74% oil and NGLs) and a 2014 exit rate of 37,000 boe/d. Average production volumes in the fourth quarter were 850 boe/d higher than our initial forecast of 36,750 boe/d, providing a strong and stable base production platform heading into 2015.

We are also pleased to present the results of our 2014 year end oil and gas reserves evaluation. Since inception we have focused on organic capital execution enhanced by an accretive and targeted acquisition strategy. This has resulted in consistent proved plus probable reserves per share growth for our shareholders at an average three year FD&A cost of $19.57/boe (including FDC) and an average recycle ratio of 2.2 times.

The financial and operational information below is based on estimates and are unaudited.

2014 RESERVE HIGHLIGHTS

• Increased proved plus probable ("2P") reserves by 66% to 219.3 MMboe (75% oil and NGLs) and proved ("1P") reserves by 64% to 155.0 MMboe (76% oil and NGLs).
• On a fully diluted per share basis, increased 2P reserves by 14% and 1P reserves by 13%.
• Achieved finding and development ("F&D") costs of $13.79 per 2P boe, including changes in future development costs ("FDC"), which results in a recycle ratio of 3.3 times.
• Achieved finding, development and acquisition ("FD&A") costs of $19.56 per 2P boe, including FDC, which results in a recycle ratio of 2.3 times.
• Increased the net present value discounted at 10% ("NPV10") of 2P reserves by 10% to $14.60 per fully diluted share and NPV10 of proved reserves by 3% to $10.87 per fully diluted share.
• Proved developed producing reserves represent 60% of 1P reserves and 42% of 2P reserves.
• 1P reserves comprise 71% of 2P reserves on a reserve basis and 74% on a NPV10 basis.
• Our organic drilling and optimization program resulted in 2P reserve additions replacing 235% of production in the year and 1P reserve additions replacing 173% of production, excluding reserves added through acquisitions.
• Including reserves added through acquisitions, 2P reserve additions replaced 833% of production in the year and 1P reserve additions replaced 610% of production.

2014 YEAR END RESERVES

Whitecap's year end 2014 reserves were evaluated by independent reserves evaluator McDaniel & Associates Consultants Ltd. ("McDaniels"). The evaluation of all of its oil and gas properties was done in accordance with the definitions, standards and procedures contained in the Canadian Oil and Gas Evaluation Handbook ("COGE Handbook") and National Instrument 51-101 - Standards of Disclosure for Oil and Gas Activities ("NI 51-101"). Additional reserve information as required under NI 51-101 will be included in the Company's Annual Information Form which will be filed on SEDAR on or before March 31, 2015.

Summary of Reserves
(Forecast Pricing)

As at December 31, 2014 ⁽¹⁾

			Company Share Reserves ^(2)
Description			Oil (Mbbl)		Gas (MMcf)		NGL (Mbbl)		Total (Mboe)
Proved producing			63,220		136,689		6,932		92,933
Proved non-producing			578		4,127		75		1,341
Proved undeveloped			42,706		82,795		4,258		60,763
Total proved ^(3)			106,504		223,611		11,265		155,037
Probable			42,742		98,779		5,014		64,219
Total proved plus probable ^(3)			149,247		322,389		16,278		219,256

^(1)	Based on McDaniels' January 1, 2015 forecast prices.
^(2)	Company share reserves are the Company's total working interest reserves before the deduction of any royalties and including any royalty interests payable to the Company.
^(3)	Numbers may not add due to rounding.

Summary of Before Tax Net Present Values
(Forecast Pricing)

As at December 31, 2014 ⁽¹⁾

		Before Tax Net Present Value ($MM)
		Discount Rate
Description			0%		5%		10%		15%		20%
Proved producing			3,643		2,543		1,954		1,593		1,352
Proved non-producing			41		27		20		15		13
Undeveloped			2,029		1,263		836		576		406
Total proved  ^(2)			5,714		3,833		2,810		2,185		1,771
Probable			3,502		1,635		965		657		489
Total proved plus probable ^(2)			9,216		5,469		3,775		2,842		2,260
Per fully diluted share			$35.65		$21.16		$14.60		$11.00		$8.74

^(1)	Based on McDaniels' January 1, 2015 forecast prices.
^(2)	Numbers may not add due to rounding.

Capital Program Efficiency

Based on the evaluation of our petroleum and natural gas reserves prepared in accordance with NI 51-101 by our independent reserve evaluator, McDaniels, the historical efficiency of our capital programs is summarized as follows:

			2014		2013		2012		Three Year Weighted Average
Capital Expenditures ($thousands)
	Development capital (organic)		250,391		152,282		148,396
	Development capital (acquisition)^(1)		68,004		34,478		95,297
	Total Development capital ^(2)		318,395		186,760		243,693
	Acquisitions (net of dispositions)^(3)		1,198,458		432,020		651,943
	Total		1,516,853		618,780		895,644
Change in 1P Future Development Costs ($thousands)
	Proved-development		138,777		166,671		47,480
	Proved-acquisition		255,110		160,050		184,490
			393,877		326,721		231,970
Change in 2P Future Development Costs ($thousands)
	Proved plus probable-development		133,688		161,272		52,379
	Proved plus probable-acquisition		279,503		165,450		188,240
			413,190		326,722		240,619
Proved Reserve Additions (mboe)
	Exploration and development		20,454		17,400		12,806
	Acquisitions (net of dispositions)		51,831		23,584		27,621
	Total		72,285		40,984		40,427
Proved plus Probable Reserve Additions (mboe)
	Exploration and development		27,836		20,519		16,387
	Acquisitions (net of dispositions)		70,815		31,742		37,660
	Total		98,651		52,261		54,047
F&D costs ($/boe)^(4)
	Proved		19.03		18.33		15.30		17.84
	Proved plus probable		13.79		15.28		12.25		13.88
FD&A costs ($/boe)
	Proved		26.43		23.07		27.89		25.92
	Proved plus probable		19.56		18.09		21.02		19.57
Ratios (based on proved plus probable reserves)
	Production replacement ^(5)		833%		724%		1054%		863%
	Recycle ratio ^(6)		2.3x		2.4x		2.0x		2.2x

(1)	Development capital (acquisition) reflects capital spending within the year on reserves that are categorized as acquisition or divestiture.
(2)	Total development capital excludes capitalized administration costs.
(3)	Acquisition capital includes the announced purchase price of corporate acquisitions including any estimated working capital deficit or surplus rather than the amounts allocated to property, plant and equipment for accounting purposes.
(4)	The aggregate of the exploration and development costs incurred in the financial year and change during that year in estimated future development costs generally will not reflect total finding and development costs related to reserve additions for that year.
(5)	Production Replacement ratio is calculated as total reserve additions (including acquisitions net of dispositions) divided by annual production. Whitecap averaged 32,450 boe/d in 2014.
(6)	Recycle ratio is calculated as operating netback divided by FD&A costs (proved plus probable). Operating netback is calculated as revenue (including realized hedging gains and losses) minus royalties, production and operating expenses and transportation expenses.  Our operating netback in 2014 was $44.95/boe.

Future Development Costs

The following table sets forth future development costs deducted in the estimation of the future net revenue attributable to the reserve categories noted below (using forecast prices and costs):

YEAR	Proved Reserves ($000s)	Proved Plus Probable Reserves ($000s)
2015	251,737	258,469
2016	334,009	360,115
2017	339,356	389,168
2018	177,916	184,640
2019	46,366	46,366
Remaining	11,812	14,142
Total (Undiscounted)	1,161,196	1,252,900

2015 REVISED GUIDANCE

In light of the continuing decline in commodity prices and the corresponding lower than projected cash flows, Whitecap's Board of Directors and Management have elected to prudently reduce our capital program by an additional 18% to $200 million effective immediately. Our previous guidance on December 16, 2014 assumed a WTI price of US$65/bbl and an AECO natural gas price of $3.25/GJ. With current crude oil prices below WTI US$50/bbl and AECO natural gas prices at approximately $2.70/GJ we felt it necessary to initiate a further capital reduction to align with the prevailing commodity price environment.

Our priority as we navigate through this challenging low price environment is to focus on balance sheet strength with a debt to cash flow ratio of approximately two times and continue to maintain the financial flexibility to accelerate our capital spending in a higher price environment. Despite the recent collapse in oil and natural gas prices our dividend remains unchanged at the current $0.0625 per month ($0.75 per annum). Whitecap funds its dividend payments through cash flow from operations and does not have a dividend reinvestment program.

We will continue to closely monitor the commodity price outlook in addition to the cost of services to ensure we protect our project economics in our major play areas and will remain diligent on the three key components of our growth and income model: decline rate, capital efficiencies and cash flow netback.

1. Decline rate:  With the lower capital spending our currently low decline rate of 23% decreases further to a projected 20% as we move into 2016.
2. Capital efficiencies:  To date in 2015 we have experienced service cost reductions of between 8-12% on our first quarter capital program. Reducing and deferring our 2015 capital spending further allows us to get better clarity on what service sector cost reductions can be realized should low commodity prices persist.  This will allow us to further optimize our program for the current environment and will positively impact both our capital efficiencies and well economics.
3. Cash flow netback:  We cannot accurately predict when commodity prices may stabilize or recover, and therefore feel that producing and monetizing a significant portion of our production today should be deferred to a time when commodity prices and cash flow netbacks are higher.

2015 revised guidance as follows:

				2015 New			2015 Previous			% Change
Average production (boe/d)				36,000			37,500			(4%)
	Per MM shares (fully diluted)			140			144			(3%)
	% Oil + NGLs			76%			76%			-
Funds from operations ($MM)				404			461			(12%)
Cash flow netback ($/boe)				30.75			33.70			(9%)
Development capital spending ($MM)				200			245			(18%)
Total payout ratio				97%			95%			(2%)
Net debt to funds from operations				2.1x			1.7x			24%
WTI (US$/bbl)				52.50			65.00			(19%)
Edmonton Par differential (US$/bbl)				(7.00)			(7.00)			-
CAD/USD exchange rate				0.80			0.85			(6%)
AECO gas price (C$/GJ)				2.50			3.25			(23%)

We are taking a conservative and cautious approach to 2015 as a result of continued low commodity prices. With our revised 2015 capital budget of $200 million we are able to maintain a strong balance sheet with debt to cash flow of approximately two times, production growth of 11% (1% per share) and a total payout ratio including capital and dividends of 97%. We are committed to providing our shareholders with sustainable growth and consistent dividends through this challenging environment with additional focus on long-term economic returns.

Additional Information

Whitecap is a dividend paying, oil-weighted company focused on providing sustainable monthly dividends to its shareholders and per share growth through a combination of accretive oil-based acquisitions and organic growth on existing and acquired assets. For further information about Whitecap please visit our website at www.wcap.ca.

Note Regarding Forward-Looking Statements and Other Advisories

This press release contains forward-looking statements and forward-looking information (collectively "forward-looking information") within the meaning of applicable securities laws relating to the Company's plans and other aspects of our anticipated future operations, management focus, strategies, financial, operating and production results and business opportunities. Forward-looking information typically uses words such as "anticipate", "believe", "project", "expect", "goal", "plan", "intend" or similar words suggesting future outcomes, statements that actions, events or conditions "may", "would", "could" or "will" be taken or occur in the future, including statements about our strategy, plans and focus, timing of filing the Company's annual information form, forecast annual average production, funds from operations and cash flow netbacks, plans to focus on balance sheet strength, debt to cash flow ratios, the Company's ability to accelerate capital spending, dividend policy, base production decline rate, capital efficiencies, anticipated service cost reductions, planned capital expenditures, total payout ratios, and drilling, development and completion plans and the anticipated results therefrom. Statements relating to "reserves" are also deemed to be forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves described exist in the quantities predicted or estimated and that the reserves can be profitably produced in the future.

The forward-looking information is based on certain key expectations and assumptions made by our management, including expectations and assumptions concerning prevailing commodity prices, exchange rates, interest rates, applicable royalty rates and tax laws; future production rates and estimates of operating costs; performance of existing and future wells; reserve and resource volumes; anticipated timing and results of capital expenditures; the success obtained in drilling new wells; the sufficiency of budgeted capital expenditures in carrying out planned activities; the timing, location and extent of future drilling operations; the state of the economy and the exploration and production business; results of operations; performance; business prospects and opportunities; the availability and cost of financing, labour and services; the impact of increasing competition; ability to efficiently integrate assets and employees acquired through acquisitions, ability to market oil and natural gas successfully and our ability to access capital.

All reserve references in this press release are "Company share reserves". Company share reserves are the Company's total working interest share of reserves before the deduction of any royalties and including any royalty interests of the Company.

Although we believe that the expectations and assumptions on which such forward-looking information is based are reasonable, undue reliance should not be placed on the forward-looking information because Whitecap can give no assurance that they will prove to be correct. Since forward-looking information addresses future events and conditions, by its very nature they involve inherent risks and uncertainties. Our actual results, performance or achievement could differ materially from those expressed in, or implied by, the forward-looking information and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking information will transpire or occur, or if any of them do so, what benefits that we will derive therefrom. Management has included the above summary of assumptions and risks related to forward-looking information provided in this press release in order to provide securityholders with a more complete perspective on our future operations and such information may not be appropriate for other purposes.

It should not be assumed that the present worth of estimated future cash flow presented in the tables above represents the fair market value of the reserves. There is no assurance that the forecast prices and costs assumptions will be attained and variances could be material. The recovery and reserve estimates of Whitecap's crude oil, natural gas liquids and natural gas reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual crude oil, natural gas and natural gas liquids reserves may be greater than or less than the estimates provided herein.

All future net revenues are stated prior to provision for interest, general and administrative expenses and after deduction of royalties, operating costs and estimated future capital expenditures. Future net revenues have been presented on a before tax basis. Estimated values of future net revenue disclosed herein do not represent fair market value.

Finding and development costs both including and excluding acquisitions and dispositions have been presented above. While NI 51-101 requires that the effects of acquisitions and dispositions be excluded, FD&A costs have been presented because acquisitions and dispositions can have a significant impact on the Company's ongoing reserve replacement costs and excluding these amounts could result in an inaccurate portrayal of the Company's cost structure.

Readers are cautioned that the foregoing lists of factors are not exhaustive. Additional information on these and other factors that could affect our operations or financial results are included in reports on file with applicable securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com).

These forward-looking statements are made as of the date of this press release and we disclaim any intent or obligation to update publicly any forward-looking information, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.

Non-GAAP Measures

This press release includes non-GAAP measures as further described herein. These non-GAAP measures do not have a standardized meaning prescribed by International Financial Reporting Standards ("IFRS" or, alternatively, "GAAP") and therefore may not be comparable with the calculation of similar measures by other companies.

"Funds from operations" represents cash flow from operating activities adjusted for changes in non-cash working capital, transaction costs and settlement of decommissioning liabilities. Management considers funds from operations and funds from operations per share to be key measures as they demonstrate Whitecap's ability to generate the cash necessary to pay dividends, repay debt, fund settlement of decommissioning liabilities and make capital investments. Management believes that by excluding the temporary impact of changes in non-cash operating working capital, funds from operations provides a useful measure of Whitecap's ability to generate cash that is not subject to short-term movements in non-cash operating working capital.

"Operating netbacks" are determined by deducting royalties, production expenses and transportation and selling expenses from oil and gas revenue. Operating netbacks are per boe measures used in operational and capital allocation decisions.

"Cash flow netbacks" are determined by deducting cash general and administrative and interest expense from Operating netbacks.

"Total payout ratio" is calculated as development capital plus cash dividends declared divided by funds from operations.

"Net debt" is calculated as bank debt plus working capital surplus or deficit adjusted for risk management contracts. Net debt is used by management to analyze the financial position and leverage of Whitecap.

"Boe" means barrel of oil equivalent on the basis of 6 mcf of natural gas to 1 bbl of oil. Boe's may be misleading, particularly if used in isolation. A boe conversion ratio of 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. In addition, 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 on a 6:1 basis may be misleading as an indication of value.

SOURCE Whitecap Resources Inc.

Grant Fagerheim, President & CEO or Thanh Kang, CFO, Whitecap Resources Inc., 500, 222 - 3 Avenue SW, Calgary, AB, T2P 0B4, Main Phone [phone], Fax [phone]

Related Links

www.wcap.ca