CALGARY, Aug. 8, 2013 /CNW/ – PENN WEST PETROLEUM LTD. (TSX – PWT; NYSE – PWE) (“PENN WEST” or the “COMPANY”) is pleased to announce its results for the second quarter ended June
30, 2013. All figures are in Canadian dollars unless otherwise stated.

		Three months ended June 30					Six months ended June 30
		2013		2012		% change	2013		2012		% change
Financial (millions, except per share amounts)
Gross revenues (1)		$	745	$	774	(4)	$	1,449	$	1,644	(12)
Funds flow (2)			278		272	2		545		609	(11)
	Basic per share (2)		0.57		0.57	–		1.13		1.29	(12)
	Diluted per share (2)		0.57		0.57	–		1.13		1.29	(12)
Net income (loss)			(40)		235	(100)		(137)		294	(100)
	Basic per share		(0.08)		0.50	(100)		(0.28)		0.62	(100)
	Diluted per share		(0.08)		0.50	(100)		(0.28)		0.62	(100)
Exploration and development capital (3)			112		329	(66)		539		989	(46)
Debt at period-end		$	3,125	$	3,691	(15)	$	3,125	$	3,691	(15)
Dividends (millions)
Dividends paid (4)		$	130	$	128	2	$	259	$	255	2
DRIP			(26)		(29)	(10)		(54)		(56)	(4)
Dividends paid in cash		$	104	$	99	5	$	205	$	199	3
Operations
Daily production (average)
	Light oil and NGL (bbls/d)		72,493		87,536	(17)		72,708		88,282	(18)
	Heavy oil (bbls/d)		15,653		17,222	(9)		15,987		17,696	(10)
	Natural gas (mmcf/d)		312		351	(11)		316		356	(11)
Total production (boe/d) (5)			140,083		163,181	(14)		141,436		165,301	(14)
Average sales price
	Light oil and NGL (per bbl)	$	82.65	$	75.20	10	$	81.44	$	79.72	2
	Heavy oil (per bbl)		67.10		61.36	9		58.81		67.17	(12)
	Natural gas (per mcf)	$	3.70	$	1.98	87	$	3.44	$	2.14	61
Netback per boe
	Sales price	$	58.49	$	51.06	15	$	56.20	$	54.37	3
	Risk management gain (loss)		(0.07)		0.29	(100)		0.26		(0.49)	100
	Net sales price		58.42		51.35	14		56.46		53.88	5
	Royalties		(10.32)		(9.84)	5		(9.81)		(10.22)	(4)
	Operating expenses		(16.83)		(17.16)	(2)		(16.86)		(17.55)	(4)
	Transportation		(0.59)		(0.51)	16		(0.59)		(0.50)	18
	Netback (2)	$	30.68	$	23.84	29	$	29.20	$	25.61	14

(1)	Gross revenues include realized gains and losses on commodity contracts.
(2)	The terms “funds flow”, “funds flow per share-basic”, “funds flow per share-diluted” and “netback” are non-GAAP measures. Please refer to the “Calculation of Funds Flow” and “Non-GAAP Measures Advisory” sections below.
(3)	Includes capital carried by partners.
(4)	Includes dividends paid prior to amounts reinvested in shares under the dividend reinvestment plan.
(5)	Please refer to the “Oil and Gas Information Advisory” section below for information regarding the term “boe”.

PRESIDENT’S MESSAGE

Dave Roberts, President and Chief Executive Officer, commented, “In the
second quarter, Penn West continued to deliver operating results in
line with expectations as we focused on reliable and repeatable
performance from our asset base. Total production for the quarter
averaged 140,083 boe per day with 63 percent being liquids. Funds flow
of $278 million for the second quarter of 2013 was higher than the
prior year due to narrowing WTI to Edmonton light sweet oil pricing
differentials, which more than offset lower production as a result of
asset dispositions closed in late 2012. Based on our performance to
date, we can reiterate our expected production guidance for the year to
deliver an annualized 135,000 to 145,000 boe per day in 2013. Capital
expenditures for the year are expected at $900 million.”

“In addition to the strategic review of the Company being progressed by
the Special Committee of the Board, we are actively streamlining and
focusing our management and operating structure. To date in 2013, the
Company has reduced its workforce by over 10 percent of full time
equivalents including a realignment of responsibilities and significant
reduction of personnel, including at the executive and management
level. Further steps to improve our focus, accountability and cost
model to allow us to achieve our goal to deliver best in class
operating performance and shareholder returns are expected in the
present quarter.”

SECOND QUARTER KEY POINTS

• Total average production of 140,083 boe per day (63 percent liquids).
• Funds flow up as commodity price gains and cost reductions offset asset
  sales.
• Staff reduction target of 10 percent on the year, achieved prior to the
  end of the quarter.
• 2013 annual average production target re-confirmed between 135,000 and
  145,000 boe per day.
• 2013 capital re-confirmed at $900 million.

OPERATIONAL HIGHLIGHTS

Second quarter 2013 production was ahead of plan as we reduced our cycle
times from the start of drilling wells to on production. This continued
to result in new production coming on-stream ahead of plans and
downward trending costs. For the first six months of 2013, average
production was 141,436 boe per day, in-line with our expectations and
our annual average production guidance. Production for the second
quarter of 2013 and year-to-date in 2013 was lower than the
corresponding periods of 2012 due to the asset dispositions completed
in the fourth quarter of 2012.

During the second quarter of 2013, exploration and development capital
expenditures totalled $112 million (2012 – $329 million). Second
quarter development activities were focused on completion and tie-in
work from our winter drilling program, notably in the Viking and
Spearfish plays. For the first six months of 2013, exploration and
development capital expenditures totalled $539 million (2012 – $989
million).

We remain on target to meet our capital guidance for 2013. The
incremental capital wedge of $300 million previously contemplated by
the Company will not be invested in 2013.

FINANCIAL HIGHLIGHTS

Funds flow for the second quarter of 2013 was $278 million ($0.57 per
share – basic) and ahead of budget due to stronger crude oil prices and
narrower WTI to Edmonton light-oil differentials. This compared to $267
million ($0.55 per share – basic) in the first quarter of 2013 with
both quarters including the effect of the late 2012 asset dispositions.

In the second quarter of 2013, we recorded a loss of $40 million ($0.08
per share – basic) primarily due to unrealized foreign exchange losses
on our U.S. denominated debt, as a result of the weakening of the
Canadian dollar relative to the US dollar.

For the second half of 2013, we currently have 55,000 barrels per day of
crude oil production hedged between US$91.55 and US$104.42 per barrel
and approximately 175,000 mcf per day of natural gas production hedged
at $3.43 per mcf.

For the first six months of 2014, we have 26,000 barrels per day of
crude oil production hedged, with 20,000 barrels per day swapped at an
average price of US$93.74 per barrel and 6,000 barrels per day collared
between US$92.00 and US$98.67 per barrel. Additionally, we have 2014
natural gas production hedged with 90,000 mcf per day swapped at $3.90
per mcf and 50,000 mcf per day collared between $3.41 per mcf and $4.17
per mcf.

PLAY UPDATE

Cardium

In the first half of 2013, we completed a selective drilling program in
the Cardium focusing on program capital efficiencies and advancement of
slick water fracture stimulation techniques. In the Alder Flats area,
drilling and completion costs in the first half of 2013 improved by
more than 30 percent from 2012. Based upon these results and extensive
study by our teams, we are confident that comparable savings can be
repeated in the Willesden Green and Lodgepole areas of the Cardium. The
Cardium represents an opportunity to create repeatable and sustainable
value creative investment programs and we will be reallocating $40
million of capital to the play in the second half of 2013. As a result
of this shift, we anticipate drilling 14 additional wells. We expect
that a continuous, even flow drilling approach will allow us to further
improve our performance in the future.

Viking

The results of our drilling program in early 2013 remain encouraging and
we have achieved significant improvements in well performance and cost.
Drilling cost and cycle times of our program are competitive with other
industry players. Our completion costs in the Viking trend higher than
most of our competitors due to our use of nitrogen in our completion
technique, however, first year well productivity is more than 25
percent higher than those of our competitors, more than justifying the
additional cost. We believe further cost improvements are possible with
pad drilling, continued refinement of our completion techniques and
continuous improvement in our drilling performance. Based upon our
results to date in the first half of 2013, we will reallocate $47
million to this opportunity in the second half with the expectation of
drilling and completing 32 new wells. In addition, we are evaluating
down spacing in the core of the play for 2014 drilling and are pursuing
the implementation of waterflood schemes to increase the recoveries and
value from this play.

Spearfish

In the first half of 2013, we allocated significant capital to the
Spearfish due to its strong capital efficiencies and the production
infrastructure in place. During the second quarter of 2013, activity
was concentrated on tie-ins and completions of the winter drilling
program and our liquids extraction plant became operational, providing
incremental natural gas liquids production.

While there are a significant number of further primary locations to
pursue in the play, we are shifting our activities to the assessment of
waterflood schemes and other pressure maintenance opportunities to
increase recoveries from the current estimate of approximately two
percent. Capital previously planned for the Spearfish is being directed
to the Cardium and Viking as we continue to study the results of our
recent aggressive three-year drilling program.

Carbonates

Our results in the first half of 2013 have met or exceeded our
expectations for cost and cycle time reductions as well as production
performance. Well costs have declined 30 percent with the 2013 program
and, for the remainder of 2013; our focus is on the initiation of a
waterflood pilot in the Otter area and preparation of integrated
development programs across the Slave Point play for 2014 and beyond.

Secondary Recovery

We remain confident in the potential to increase recoveries and create
incremental value from the application of waterflood and other enhanced
oil recovery schemes. Significant reservoir simulation work across all
of our major plays has been completed with encouraging results. Over
the balance of 2013 and into 2014, we will be implementing or expanding
waterfloods in the Cardium and Slave Point, and will be evaluating
waterflood application to the Viking and Spearfish. As we focus on
enhancing value and capital returns by increasing resource recoveries,
we expect a higher portion of our future capital programs will include
upfront waterflood investments.

DIVIDENDS

On August 7, 2013, our Board of Directors declared a third quarter 2013
dividend of $0.14 per share to be paid on October 15, 2013 to
shareholders of record at the close of business on September 30, 2013.
Shareholders are advised that this dividend is designated as an
“eligible dividend” for Canadian income tax purposes.

DRILLING STATISTICS
	Three months ended June 30								Six months ended June 30
	2013				2012				2013			2012
	Gross		Net		Gross		Net		Gross		Net		Gross		Net
Oil	12		1		19		12		156		119		207		163
Natural gas	–		–		–		–		1		1		20		17
	12		1		19		12		157		120		227		180
Stratigraphic and service	–		–		2		1		33		16		52		28
Total	12		1		21		13		190		136		279		208
Success rate (1)			100%				100%				100%				100%

(1)	Success rate is calculated excluding stratigraphic and service wells.

CAPITAL EXPENDITURES
(millions)	Three months ended June 30						Six months ended June 30
	2013			2012			2013			2012
Land acquisition and retention	$	2		$	27		$	3		$	35
Drilling and completions		70			179			391			676
Facilities and well equipping		65			138			194			337
Geological and geophysical		–			2			9			10
Corporate		2			3			5			11
Capital carried by partners		(27)			(20)			(63)			(80)
Exploration and development capital (1)		112			329			539			989
Property dispositions, net		(29)			(19)			(38)			(341)
Total expenditures	$	83		$	310		$	501		$	648

(1)	Exploration and development capital includes costs related to Property, Plant and Equipment and Exploration and Evaluation activities.

In the second quarter of 2013, our activities were focused on
completions and tie-in work from our winter drilling program in early
2013.

LAND
	As at June 30
		Producing						Non-producing
		2013		2012		% change		2013		2012		% change
Gross acres (000s)		5,244		5,974		(12)		3,011		2,859		5
Net acres (000s)		3,558		4,028		(12)		2,061		2,130		(3)
Average working interest		68%		67%		1		69%		75%		(6)

COMMON SHARE DATA
			Three months ended June 30						Six months ended June 30
(millions of shares)			2013		2012		% change		2013		2012	% change
Weighted average
	Basic		484.6		474.3		2		483.2		473.5	2
	Diluted		484.6		474.4		2		483.2		473.6	2
Outstanding as at June 30									485.0		474.6	2

Outlook

This outlook section is included to provide shareholders with
information about our expectations as at August 7, 2013 for production
and capital expenditures in 2013 and readers are cautioned that the
information may not be appropriate for any other purpose. This
information constitutes forward-looking information. Readers should
note the assumptions, risks and discussion under “Forward-Looking
Statements” and are cautioned that numerous factors could potentially
impact our capital expenditure levels and production performance for
2013.

Our 2013 exploration and development capital budget remains unchanged at
$900 million. It has been determined not to proceed with the previously
announced option to increase our 2013 capital budget by $300 million.
Our forecast 2013 average production remains unchanged between 135,000
and 145,000 boe per day.

There have been no changes to our guidance from our initial forecast,
released on January 9, 2013 with our “2013 Budget” release and filed on
SEDAR at www.sedar.com.

Non-GAAP Measures Advisory

This news release includes non-GAAP measures not defined under
International Financial Reporting Standards (“IFRS”) including funds
flow, funds flow per share-basic, funds flow per share-diluted and
netback. Non-GAAP measures do not have any standardized meaning
prescribed by GAAP and therefore may not be comparable to similar
measures presented by other issuers. Funds flow is cash flow from
operating activities before changes in non-cash working capital and
decommissioning expenditures. Funds flow is used to assess our ability
to fund dividends and planned capital programs. See “Calculation of
Funds Flow” below. Netback is a per-unit-of-production measure of
operating margin used in capital allocation decisions, to economically
rank projects and is the per unit of production amount of revenue less
royalties, operating costs, transportation and realized risk management
gains and losses.

Calculation of Funds Flow
(millions, except per share amounts)		Three months ended June 30							Six months ended June 30
		2013		2012					2013		2012
Cash flow from operating activities		$	199	$	280				$	455	$	514
Change in non-cash working capital			72		(23)					65		56
Decommissioning expenditures			7		15					25		39
Funds flow		$	278	$	272				$	545	$	609
Basic per share		$	0.57	$	0.57				$	1.13	$	1.29
Diluted per share		$	0.57	$	0.57				$	1.13	$	1.29

Oil and Gas Information Advisory

Barrels of oil equivalent (“boe”) may be misleading, particularly if
used in isolation. A boe conversion ratio of six thousand cubic feet of
natural gas to one barrel of crude oil is based on an energy
equivalency conversion method primarily applicable at the burner tip
and does not represent a value equivalency at the wellhead. 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
conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is
misleading as an indication of value.

Forward-Looking Statements

Certain statements contained in this document constitute forward-looking
statements or information (collectively “forward-looking statements”)
within the meaning of the “safe harbour” provisions of applicable
securities legislation. Forward-looking statements are typically
identified by words such as “anticipate”, “continue”, “estimate”,
“expect”, “forecast”, “may”, “will”, “project”, “could”, “plan”,
“intend”, “should”, “believe”, “outlook”, “objective”, “aim”,
“potential”, “target” and similar words suggesting future events or
future performance. In particular, this document contains
forward-looking statements pertaining to, without limitation, the
following: under “President’s Message”, “Second Quarter Key Points” and
“Outlook”, our 2013 exploration and development capital budget of $900
million, and our forecast 2013 average production of between 135,000
and 145,000 boe per day; under “President’s Message”, our intention to
progress a strategic review of the Company, our intention to actively
streamline and focus our management and operating structure, and our
belief that further steps to improve our focus, accountability and cost
model to allow us to achieve our goal to deliver best in class
operating performance and shareholder returns are expected in the
present quarter; under “Play Update – Cardium”, our belief that savings
comparable to those achieved at Alder Flats can be repeated in the
Willesden Green and Lodgepole areas, our belief that the Cardium
represents an opportunity to create repeatable and sustainable value
creative investment programs, our intention to reallocate $40 million
of capital to the play in the second half of 2013 and drill 14
additional wells, and our expectation that a continuous, even flow
drilling approach will allow us to further improve our performance in
the future; under “Play Update – Viking”, our belief that further cost
improvements are possible with pad drilling, continued refinement of
our completion techniques and continuous improvement in our drilling
performance, our intention to reallocate $47 million to this play in
the second half with the expectation of drilling and completing 32 new
wells, and our intention to evaluate down spacing in the core of the
play for 2014 drilling and pursue the implementation of waterflood
schemes to increase the recoveries and value from this play; under
“Play Update – Spearfish”, our belief that there are a significant
number of further primary locations to pursue in the play, our
intention to shift our activities to the assessment of waterflood
schemes and other pressure maintenance opportunities to increase
recoveries from the current estimate of approximately two percent, and
our plan that capital previously planned for the area will be directed
to the Cardium and Viking as we continue to study the results of our
recent aggressive three-year drilling program in the Spearfish area;
under “Play Update – Carbonates”, our intention that for the remainder
of 2013 our focus will be on the initiation of a waterflood pilot in
the Otter area and preparation of integrated development programs
across the Slave Point play for 2014 and beyond; and under “Play Update
– Secondary Recovery”, our confidence in the potential to increase
recoveries and create incremental value from the application of
waterflood and other enhanced oil recovery schemes, our plan that over
the balance of 2013 and into 2014 we will implement or expand
waterfloods in the Cardium and Slave Point, and will evaluate
waterflood application to the Viking and Spearfish, and our expectation
that as we focus on enhancing value and capital returns by increasing
resource recoveries, a higher portion of our future capital programs
will include upfront waterflood investments.

With respect to forward-looking statements contained in this document,
we have made assumptions regarding, among other things: future crude
oil, natural gas liquids and natural gas prices and differentials
between light, medium and heavy oil prices and Canadian, WTI and world
oil prices; future capital expenditure levels; future crude oil,
natural gas liquids and natural gas production levels; drilling
results; future exchange rates and interest rates; the amount of future
cash dividends that we intend to pay and the level of participation in
our dividend reinvestment plan; our ability to obtain equipment in a
timely manner to carry out development activities and the costs
thereof; our ability to market our oil and natural gas successfully to
current and new customers; our ability to obtain financing on
acceptable terms, including our ability to renew or replace our credit
facility and our ability to finance the repayment of our senior
unsecured notes on maturity; and our ability to add production and
reserves through our development and exploitation activities. In
addition, many of the forward-looking statements contained in this
document are located proximate to assumptions that are specific to
those forward-looking statements, and such assumptions should be taken
into account when reading such forward-looking statements.

Although we believe that the expectations reflected in the
forward-looking statements contained in this document, and the
assumptions on which such forward-looking statements are made, are
reasonable, there can be no assurance that such expectations will prove
to be correct. Readers are cautioned not to place undue reliance on
forward-looking statements included in this document, as there can be
no assurance that the plans, intentions or expectations upon which the
forward-looking statements are based will occur. By their nature,
forward-looking statements involve numerous assumptions, known and
unknown risks and uncertainties that contribute to the possibility that
the predictions, forecasts, projections and other forward-looking
statements will not occur, which may cause our actual performance and
financial results in future periods to differ materially from any
estimates or projections of future performance or results expressed or
implied by such forward-looking statements. These risks and
uncertainties include, among other things: the impact of weather
conditions on seasonal demand and ability to execute capital programs;
risks inherent in oil and natural gas operations; uncertainties
associated with estimating reserves and resources; competition for,
among other things, capital, acquisitions of reserves, resources,
undeveloped lands and skilled personnel; incorrect assessments of the
value of acquisitions; geological, technical, drilling and processing
problems; general economic and political conditions in Canada, the U.S.
and globally; industry conditions, including fluctuations in the price
of oil and natural gas, price differentials for crude oil produced in
Canada as compared to other markets, and transportation restrictions;
royalties payable in respect of our oil and natural gas production and
changes to government royalty frameworks; changes in government
regulation of the oil and natural gas industry, including environmental
regulation; fluctuations in foreign exchange or interest rates;
unanticipated operating events or environmental events that can reduce
production or cause production to be shut-in or delayed, including wild
fires and flooding; failure to obtain regulatory, industry partner and
other third-party consents and approvals when required, including for
acquisitions, dispositions and mergers;  failure to realize the
anticipated benefits of dispositions, acquisitions, joint ventures and
partnerships; changes in tax and other laws that affect us and our
securityholders; ; the potential failure of counterparties to honour
their contractual obligations; and the other factors described in our
public filings (including our Annual Information Form) available in
Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be
construed as exhaustive.

The forward-looking statements contained in this document speak only as
of the date of this document. Except as expressly required by
applicable securities laws, we do not undertake any obligation to
publicly update or revise any forward-looking statements, whether as a
result of new information, future events or otherwise. The
forward-looking statements contained in this document are expressly
qualified by this cautionary statement.

Penn West Petroleum Ltd. Consolidated Balance Sheets
(CAD millions, unaudited)		June 30, 2013			December 31, 2012
Assets
Current
	Accounts receivable	$	368		$	364
	Other		64			79
	Deferred funding assets		118			187
	Risk management		35			76
			585			706
Non-current
	Deferred funding assets		250			238
	Exploration and evaluation assets		669			609
	Property, plant and equipment		10,869			10,892
	Goodwill		2,020			2,020
	Risk management		56			26
			13,864			13,785
Total assets		$	14,449		$	14,491
Liabilities and Shareholders’ Equity
Current
	Accounts payable and accrued liabilities	$	614		$	764
	Dividends payable		131			129
	Current portion of long-term debt		63			5
	Risk management		37			9
			845			907
Non-current
	Long-term debt		3,062			2,685
	Decommissioning liability		639			635
	Risk management		32			35
	Deferred tax liability		1,324			1,350
	Other non-current liabilities		7			5
			5,909			5,617
Shareholders’ equity
	Shareholders’ capital		9,067			8,985
	Other reserves		79			97
	Deficit		(606)			(208)
			8,540			8,874
Total liabilities and shareholders’ equity		$	14,449		$	14,491

Penn West Petroleum Ltd. Consolidated Statements of Income (Loss)
			Three months ended June 30						Six months ended June 30
(CAD millions, except per share amounts, unaudited)				2013		2012			2013		2012
	Oil and natural gas sales			$	746	$	770		$	1,442	$	1,659
	Royalties				(132)		(147)			(251)		(308)
					614		623			1,191		1,351
	Risk management gain (loss)
		Realized			(1)		4			7		(15)
		Unrealized			34		363			(39)		300
					647		990			1,159		1,636
Expenses
	Operating				214		255			431		528
	Transportation				7		7			15		15
	General and administrative				43		44			86		83
	Restructuring				13		–			13		–
	Share-based compensation				16		(30)			24		(13)
	Depletion and depreciation				270		306			549		618
	Gain on dispositions				–		(23)			–		(95)
	Exploration and evaluation				–		–			–		1
	Unrealized risk management (gain) loss				2		19			(3)		(23)
	Unrealized foreign exchange loss				64		35			93		4
	Financing				47		49			92		96
	Accretion				11		10			22		21
					687		672			1,322		1,235
Income (loss) before taxes					(40)		318			(163)		401
	Deferred tax expense (recovery)				–		83			(26)		107
Net and comprehensive income (loss)				$	(40)	$	235		$	(137)	$	294
Net income (loss) per share
	Basic			$	(0.08)	$	0.50		$	(0.28)	$	0.62
	Diluted			$	(0.08)	$	0.50		$	(0.28)	$	0.62
Weighted average shares outstanding (millions)
	Basic				484.6		474.3			483.2		473.5
	Diluted				484.6		474.4			483.2		473.6

Penn West Petroleum Ltd. Consolidated Statements of Cash Flows
		Three months ended June 30							Six months ended June 30
(CAD millions, unaudited)			2013		2012				2013			2012
Operating activities
	Net income (loss)		$	(40)		$	235		$	(137)		$	294
	Depletion and depreciation			270			306			549			618
	Gain on dispositions			–			(23)			–			(95)
	Exploration and evaluation			–			–			–			1
	Accretion			11			10			22			21
	Deferred tax expense (recovery)			–			83			(26)			107
	Share-based compensation			5			(30)			8			(18)
	Unrealized risk management loss (gain)			(32)			(344)			36			(323)
	Unrealized foreign exchange loss			64			35			93			4
	Decommissioning expenditures			(7)			(15)			(25)			(39)
	Change in non-cash working capital			(72)			23			(65)			(56)
				199			280			455			514
Investing activities
	Capital expenditures			(112)			(329)			(539)			(989)
	Property dispositions (acquisitions), net			29			19			38			341
	Change in non-cash working capital			(112)			(131)			(94)			(139)
				(195)			(441)			(595)			(787)
Financing activities
	Increase in bank loan			100			260			343			469
	Issue of equity			–			–			2			3
	Dividends paid			(104)			(99)			(205)			(199)
				(4)			161			140			273
Change in cash				–			–			–			–
Cash, beginning of period				–			–			–			–
Cash, end of period			$	–		$	–		$	–		$	–

Penn West Petroleum Ltd. Statements of Changes in Shareholders’ Equity
(CAD millions, unaudited)
		Shareholders’ Capital		Other Reserves		Deficit		Total
Balance at January 1, 2013		$	8,985	$	97	$	(208)	$	8,874
Net and comprehensive loss			–		–		(137)		(137)
Share-based compensation			–		8		–		8
Issued on exercise of options and share rights			28		(26)		–		2
Issued to dividend reinvestment plan			54		–		–		54
Dividends declared			–		–		(261)		(261)
Balance at June 30, 2013		$	9,067	$	79	$	(606)	$	8,540
(CAD millions, unaudited)		Shareholders’ Capital		Other Reserves		Retained Earnings		Total
Balance at January 1, 2012		$	8,840	$	95	$	132	$	9,067
Net and comprehensive income			–		–		294		294
Share-based compensation			–		17		–		17
Issued on exercise of options and share rights			21		(18)		–		3
Issued to dividend reinvestment plan			56		–		–		56
Dividends declared			–		–		(256)		(256)
Balance at June 30, 2012		$	8,917	$	94	$	170	$	9,181

Investor Information

Penn West shares are listed on the Toronto Stock Exchange under the
symbol PWT and on the New York Stock Exchange under the symbol PWE.

A conference call will be held to discuss Penn West’s results at 9:00am
Mountain Time (11:00am Eastern Time) on Thursday, August 8, 2013.

To listen to the conference call, please call 647-427-7450 or
1-888-231-8191 (toll-free). This call will be broadcast live on the
Internet and may be accessed directly at the following URL: http://event.on24.com/r.htm?e=662540&s=1&k=7C51AB755D519A86E91ACDD6834B5428

A digital recording will be available for replay two hours after the
call’s completion, and will remain available until August 22, 2013
21:59 Mountain Time (23:59 Eastern Time). To listen to the replay,
please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter
Conference ID 21336235, followed by the pound (#) key.

 

 

SOURCE: Penn West Exploration