CALGARY,
AB, Oct. 27, 2022 /CNW/ - Whitecap Resources
Inc. ("Whitecap" or the "Company") (TSX: WCP) is pleased to report
its operating and unaudited consolidated financial results for the
three and nine months ended September 30,
2022.
Selected financial and operating information is outlined below
and should be read with Whitecap's unaudited interim consolidated
financial statements and related Management's Discussion and
Analysis for the three and nine months ended September 30, 2022 which are available at
www.sedar.com and on our website at www.wcap.ca.
FINANCIAL AND OPERATING HIGHLIGHTS
Financial ($000s
except for share amounts
and percentages)
|
Three months ended
September 30
|
|
Nine months ended
September 30
|
2022
|
2021
|
2022
|
|
2021
|
Petroleum and natural
gas revenues
|
|
1,070,509
|
|
678,115
|
|
3,336,375
|
|
1,740,527
|
Net income
|
|
324,464
|
|
1,514,633
|
|
1,357,454
|
|
1,552,826
|
Basic
($/share)
|
|
0.53
|
|
2.40
|
|
2.19
|
|
2.64
|
Diluted
($/share)
|
|
0.53
|
|
2.37
|
|
2.17
|
|
2.62
|
Funds flow
1
|
|
546,788
|
|
293,741
|
|
1,729,121
|
|
748,072
|
Basic
($/share)
|
|
0.89
|
|
0.46
|
|
2.80
|
|
1.27
|
Diluted
($/share)
|
|
0.88
|
|
0.46
|
|
2.77
|
|
1.26
|
Dividends paid or
declared
|
|
67,232
|
|
30,807
|
|
169,991
|
|
83,772
|
Per share
|
|
0.11
|
|
0.05
|
|
0.28
|
|
0.14
|
Expenditures on
property, plant and equipment 2
|
208,004
|
|
135,204
|
|
507,529
|
|
293,486
|
Total payout ratio (%)
1
|
|
50
|
|
57
|
|
39
|
|
50
|
Net Debt
1
|
|
2,192,263
|
|
1,313,871
|
|
2,192,263
|
|
1,313,871
|
Operating
|
|
|
|
|
|
|
|
|
Average daily
production
|
|
|
|
|
|
|
|
|
Crude oil
(bbls/d)
|
|
85,137
|
|
77,188
|
|
84,599
|
|
74,063
|
NGLs
(bbls/d)
|
|
16,513
|
|
10,279
|
|
14,863
|
|
10,368
|
Natural gas
(Mcf/d)
|
|
264,886
|
|
170,807
|
|
225,076
|
|
150,979
|
Total (boe/d)
3
|
|
145,798
|
|
115,935
|
|
136,975
|
|
109,594
|
Average realized Price
4,5
|
|
|
|
|
|
|
|
|
Crude oil
($/bbl)
|
|
111.64
|
|
81.02
|
|
119.13
|
|
73.75
|
NGLs
($/bbl)
|
|
55.87
|
|
45.64
|
|
58.65
|
|
37.36
|
Natural gas
($/Mcf)
|
|
4.56
|
|
3.79
|
|
5.65
|
|
3.49
|
Petroleum and natural
gas revenues ($/boe) 5
|
79.81
|
63.58
|
89.22
|
|
58.17
|
Operating Netback
($/boe) 1,5
|
|
|
|
|
|
|
|
|
Petroleum and natural
gas revenues
|
|
79.81
|
|
63.58
|
|
89.22
|
|
58.17
|
Tariffs
|
|
(0.39)
|
|
(0.43)
|
|
(0.44)
|
|
(0.41)
|
Processing & other
income
|
|
0.74
|
|
0.83
|
|
0.64
|
|
0.77
|
Marketing
revenue
|
|
6.03
|
|
4.29
|
|
6.02
|
|
3.57
|
Petroleum and natural
gas sales
|
|
86.19
|
|
68.27
|
|
95.44
|
|
62.10
|
Realized loss on
commodity contracts
|
(2.20)
|
|
(6.83)
|
|
(5.98)
|
|
(5.13)
|
Royalties
|
|
(16.29)
|
|
(10.24)
|
|
(17.58)
|
|
(9.07)
|
Operating
expenses
|
|
(14.85)
|
|
(13.71)
|
|
(14.71)
|
|
(13.61)
|
Transportation
expenses
|
|
(2.27)
|
|
(2.29)
|
|
(2.20)
|
|
(2.23)
|
Marketing
expenses
|
|
(6.00)
|
|
(4.32)
|
|
(5.97)
|
|
(3.60)
|
Operating
netbacks
|
|
44.58
|
|
30.88
|
|
49.00
|
|
28.46
|
Share information
(000s)
|
|
|
|
|
|
|
|
|
Common shares
outstanding, end of period
|
610,610
|
|
631,991
|
|
610,610
|
|
631,991
|
Weighted average basic
shares outstanding
|
611,904
|
|
632,101
|
|
618,471
|
|
588,750
|
Weighted average
diluted shares outstanding
|
617,911
|
|
638,060
|
|
624,504
|
|
593,407
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
MESSAGE TO SHAREHOLDERS
Whitecap delivered another strong quarter with the successful
execution of its $208 million capital
program to achieve average production of 145,798 boe/d in the third
quarter, well ahead of our internal expectations. Production per
share1 increased 11% compared to the second quarter of
this year and 30% compared to the same quarter in the prior
year.
The efficient execution of our capital program and strong
operational results generated $339
million of free funds flow6 in the third quarter,
of which $138 million was returned to
shareholders through our base dividend ($67
million) and share repurchases ($71
million) at an average cost of $8.45 per share.
We successfully closed the acquisition of XTO Energy Canada
("XTO") on August 31st for
net cash consideration of $1.7
billion, after working capital adjustments, resulting in
quarter end net debt of $2.2 billion
and a debt to EBITDA ratio7 of 0.8 times. Total credit
capacity is now $3.1 billion
providing us with significant financial flexibility going
forward.
Whitecap drilled 84 (68.4 net) wells during the quarter
including 60 (46.7 net) wells in Saskatchewan, 13 (12.0 net) wells in
Central Alberta, and 11 (9.7 net)
wells in Northern Alberta &
B.C.
We highlight the following third quarter 2022 financial and
operating results:
- Production Outperformance. Third quarter production of
145,798 boe/d included one month of the XTO acquired volumes and
increased 30% per share compared to Q3/21. Outperformance on our
base assets continued while execution of optimization opportunities
contributed to production outperforming our internal expectations
of 142,000 – 144,000 boe/d.
- Strong Funds Flow. Third quarter funds flow of
$547 million or $0.88 per share was up 91% as compared to Q3/21.
Funds flow per share was the second highest quarterly result in
Company history, and includes the impact of one-time transaction
costs of $11 million relating to the
XTO acquisition and higher operating costs primarily related to
third quarter Alberta power prices
averaging over 80% and over 120% higher than Q2/22 and Q3/21,
respectively.
- Return of Capital Focus. Dividends paid during the third
quarter were $67 million or
$0.11 per share, which were 22% and
137% higher on a per share basis than Q2/22 and Q3/21,
respectively. Including $71 million
of share repurchases under our normal course issuer bid ("NCIB"),
total capital returned to shareholders was $138 million during the quarter.
- Balance Sheet Strength. Quarter end net debt of
$2.2 billion represents a debt to
EBITDA ratio of 0.8x and EBITDA to interest expense
ratio7 of 55.2x, well within our covenant limits of not
greater than 4.0x and not less than 3.5x, respectively. Our balance
sheet is in excellent shape and provides significant financial
flexibility to manage through commodity price cycles.
OUTLOOK
Integration of the XTO assets has been seamless given our
existing expertise in the Montney.
Since May 2021, we have brought on
production 12 Montney wells with 4 more wells to be on stream by
the end of the year, and we are expecting to drill another 23 (21.4
net) Montney wells at Kakwa in
2023. Our four-well 12-33 pad has now achieved an average
production rate of 1,900 boe/d (36% liquids) per well over the
first 120 days on production, while the three-well 14-13 pad has
now been on for 270 days, achieving an average per well production
rate of 1,660 boe/d (29% liquids)3. These results
continue to exceed our initial expectations, further validating the
high quality of inventory acquired.
We are currently operating 9 drilling rigs and we expect
operational momentum to continue into the fourth quarter with
average production increasing by 13% to approximately 165,000 boe/d
(65% liquids). We now expect 2022 production to average 144,000
boe/d (70% liquids) which is at the high end of our previous
guidance. Our expectations for 2022 capital expenditures of
$670 - $690
million are unchanged which is expected to result in the
Company reaching our $1.8 billion net
debt milestone prior to year end at current strip
prices8.
Our 2023 budget of $900 -
$950 million and average production
guidance of 170,000 – 172,000 boe/d (64% liquids) is unchanged and
is expected to result in the Company reaching our final net debt
milestone of $1.3 billion in
mid-20238. Once we achieve our net debt milestone of
$1.3 billion, we anticipate returning
75% of free funds flow back to shareholders which includes a
targeted annual base dividend of $0.73 per share.
NEW ENERGY UPDATE
Whitecap's New Energy team continues to advance our Fort Saskatchewan carbon hub with our partners
in Alberta and our Belle Plaine/Regina carbon hub in Saskatchewan with spending on pre-FID ("final
investment decision") work, seismic and evaluation wells. In
addition to these two projects, Whitecap, along with our partners,
was successful in being selected by the Government of Alberta to pursue the development of two
additional strategically located carbon hubs to transport and
permanently sequester CO2 emissions captured from
sources in Central and Southern
Alberta.
- Rolling Hills Hub. Whitecap and AltaGas Ltd. ("AltaGas")
have partnered for a potential open-access carbon sequestration hub
to the northwest of Calgary in
Southern Alberta. The project has
identified multiple CO2 emission sources in the area and
includes facilities owned and operated by both Whitecap and
AltaGas. The project's next step is to commence a technical
evaluation with a potential in-service date of 2026.
- Central Alberta Hub. Whitecap and Wolf Midstream have
partnered for a potential open-access carbon sequestration hub east
of Red Deer in Central Alberta. The hub will be connected to
the Alberta Carbon Trunk Line and will leverage this existing
infrastructure along with our subsurface knowledge in the area. The
project's next step is to commence a technical evaluation with a
potential in-service date of 2027.
We will continue to advance these projects forward to provide
safe and reliable transportation and storage solutions for
industrial parties. We are confident that our technical expertise
and experience operating existing carbon sequestration projects
both in Saskatchewan and
Alberta will provide the necessary
support for industrial parties wishing to pursue decarbonization
plans at an accelerated pace.
On behalf of our employees, management team and Board of
Directors, we would like to thank our shareholders for their
support and look forward to updating you on our progress through
the remainder of the year and into 2023.
CONFERENCE CALL AND WEBCAST
Whitecap has scheduled a conference call and webcast to begin
promptly at 9:00 am MT (11:00 am ET) on Thursday,
October 27, 2022.
The conference call dial-in number is:
1-888-390-0605 or (587) 880-2175 or (416) 764-8609
A live audio webcast of the conference call will be accessible
on Whitecap's website at www.wcap.ca by selecting
"Investors", then "Presentations & Events".
Shortly after the live webcast, an archived version will be
available.
NOTES
1
|
Funds flow, funds flow
basic ($/share), funds flow diluted ($/share) and net debt are
capital management measures. Total payout ratio and production per
share are supplementary financial measures. Operating Netback is a
non-GAAP financial measure and operating netbacks ($/boe) is a
non-GAAP ratio. Refer to the Specified Financial Measures section
in this press release for additional disclosure and
assumptions.
|
2
|
Also referred to herein
as "capital expenditures".
|
3
|
Disclosure of
production on a per boe basis in this press release consists of the
constituent product types and their respective quantities disclosed
herein. Refer to Barrel of Oil Equivalency and Production, Initial
Production Rates and Product Type Information in this press release
for additional disclosure.
|
4
|
Prior to the impact of
risk management activities and tariffs.
|
5
|
Supplementary financial
measure. Refer to the "Supplementary Financial Measures" section of
the Company's MD&A for the three and nine months ended
September 30, 2022, which is incorporated herein by reference, and
available on SEDAR at www.sedar.com.
|
6
|
Free funds flow is a
non-GAAP financial measure. Refer to the Specified Financial
Measures section in this press release for additional disclosure
and assumptions.
|
7
|
Debt to EBITDA ratio
and EBITDA to interest expense ratio are specified financial
measures that are calculated in accordance with the financial
covenants in our credit agreement.
|
8
|
See Note Regarding
Forward-Looking Statements for underlying commodity price and
exchange rate assumptions.
|
NOTE REGARDING FORWARD-LOOKING
STATEMENTS
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", "continue", "trend", "sustain",
"project", "expect", "forecast", "budget", "goal", "guidance",
"plan", "objective", "strategy", "target", "intend", "estimate",
"potential", 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, focus, objectives, priorities
and position.
In particular, and without limiting the generality of the
foregoing, this press release contains forward-looking information
with respect to: that our total credit capacity provides us with
significant financial flexibility going forward; our balance sheet
being in excellent shape and provides significant financial
flexibility to manage through commodity price cycles; our
expectation that 4 more Montney
wells will be on stream by the end of the year and we are expecting
to drill another 23 (21.4 net) Montney wells at Kakwa in 2023; our average
daily production forecast for Q4/22 (including by product type);
our average daily production (including by product type) and
capital expenditure forecasts for 2022 and 2023; our expectation to
reach our net debt milestone of $1.8
billion prior to year end based on current strip pricing;
our expectation to reach our final net debt milestone of
$1.3 billion in mid-2023; that we
anticipate returning 75% of free funds flow back to shareholders
once our $1.3 billion net debt
milestone is reached, which is expected to include a $0.73 per share annual dividend; the timing of
the potential in-service date of 2026 for the Rolling Hills carbon sequestration hub; the
timing of the potential in-service date of 2027 for the
Central Alberta carbon
sequestration hub; and that our technical expertise and experience
operating existing carbon sequestration projects will provide the
necessary support for industrial parties wishing to pursue
decarbonization plans at an accelerated pace.
The forward-looking information is based on certain key
expectations and assumptions made by our management, including:
that we will continue to conduct our operations in a manner
consistent with past operations except as specifically noted herein
(and for greater certainty, the forward-looking information
contained herein excludes the potential impact of any acquisitions
or dispositions that we may complete in the future); the general
continuance or improvement in current industry conditions; the
continuance of existing (and in certain circumstances, the
implementation of proposed) tax, royalty and regulatory regimes;
expectations and assumptions concerning prevailing and forecast
commodity prices, exchange rates, interest rates, inflation rates,
applicable royalty rates and tax laws, including the assumptions
specifically set forth herein; the impact (and the duration
thereof) that the COVID-19 pandemic will have on (i) the demand for
crude oil, NGLs and natural gas, (ii) our supply chain, including
our ability to obtain the equipment and services we require, and
(iii) our ability to produce, transport and/or sell our crude oil,
NGLs and natural gas; the ability of OPEC+ nations and other major
producers of crude oil to adjust crude oil production levels and
thereby manage world crude oil prices; the impact (and the duration
thereof) of the ongoing military actions between Russia and Ukraine and related sanctions on crude oil,
NGLs and natural gas prices; the impact of rising and/or sustained
high inflation rates and interest rates on the North American and
world economies and the corresponding impact on our costs, our
profitability, and on crude oil, NGLs and natural gas prices;
future production rates and estimates of operating costs and
development capital, including as specifically set forth herein;
performance of existing and future wells; reserve volumes and net
present values thereof; anticipated timing and results of capital
expenditures / development capital, including as specifically set
forth herein; 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; future dividend levels and share
repurchase levels; the impact of increasing competition; ability to
efficiently integrate assets and employees acquired through
acquisitions; ability to market oil and natural gas successfully;
our ability to access capital and the cost and terms thereof. In
addition: (i) our expectation to reach our net debt milestone of
$1.8 billion prior to year end is
based on the following current strip pricing and exchange rate
assumptions: October 26 –
December 31, 2022 - WTI of
US$84.46/bbl, USD/CAD of $1.36 and AECO of C$5.02/GJ; (ii) our expectation to reach our net
debt milestone of $1.3 billion in
mid-2023 is based on the following commodity pricing and exchange
rate assumptions: WTI of US$80.00/bbl, USD/CAD of $1.35 and AECO of C$5.00/GJ.
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. These include, but are not
limited to: the risk that we do not realize some or all of the
anticipated benefits of the recently completed XTO acquisition; the
risk that the funds that we ultimately return to shareholders
through dividends and/or share buybacks is less than currently
anticipated and/or is delayed, whether due to the risks identified
herein or otherwise; the risk that any of our material assumptions
prove to be materially inaccurate, including our 2022 and 2023
forecasts (including for commodity prices and exchange rates); the
risks associated with the oil and gas industry in general such as
operational risks in development, exploration and production;
pandemics and epidemics; delays or changes in plans with respect to
exploration or development projects or capital expenditures; the
uncertainty of estimates and projections relating to reserves,
production, costs and expenses; risks associated with increasing
costs, whether due to high inflation rates, high interest rates,
supply chain disruptions or other factors; health, safety and
environmental risks; commodity price and exchange rate
fluctuations; interest rate fluctuations; inflation rate
fluctuations; marketing and transportation; loss of markets;
environmental risks; competition; incorrect assessment of the value
of acquisitions; failure to complete or realize the anticipated
benefits of acquisitions or dispositions; ability to access
sufficient capital from internal and external sources on acceptable
terms or at all; failure to obtain required regulatory and other
approvals; reliance on third parties and pipeline systems; changes
in legislation, including but not limited to tax laws, production
curtailment, royalties and environmental regulations; and the risk
that the amount of future cash dividends paid by us and/or shares
repurchased for cancellation by us, if any, will be subject to the
discretion of our Board of Directors and may vary depending on a
variety of factors and conditions existing from time to time,
including, among other things, fluctuations in commodity prices,
production levels, capital expenditure requirements, debt service
requirements, operating costs, royalty burdens, foreign exchange
rates, contractual restrictions contained in our debt agreements,
and the satisfaction of the liquidity and solvency tests imposed by
applicable corporate law for the declaration and payment of
dividends and/or the repurchase of shares – depending on these and
various other factors, many of which will be beyond our control,
our dividend policy and/or share buyback policy and, as a result,
future cash dividends and/or share buybacks, could be reduced or
suspended entirely. 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
security holders with a more complete perspective on our future
operations and such information may not be appropriate for other
purposes.
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.
This press release contains future-oriented financial
information and financial outlook information (collectively,
"FOFI") about Whitecap's Q4/22, 2022 and 2023 average daily
production, 2022 and 2023 capital expenditures, the timing of
reaching our first net debt milestone of $1.8 billion, our targeted annual dividend level
and the timing thereof, the percent of free funds flow to be
returned to shareholders based on reaching our net debt milestone
of $1.3 billion and the timing
thereof all of which are subject to the same assumptions, risk
factors, limitations, and qualifications as set forth in the above
paragraphs. The actual results of operations of Whitecap and the
resulting financial results will likely vary from the amounts set
forth herein and such variation may be material. Whitecap and its
management believe that the FOFI has been prepared on a reasonable
basis, reflecting management's best estimates and judgments.
However, because this information is subjective and subject to
numerous risks, it should not be relied on as necessarily
indicative of future results. Except as required by applicable
securities laws, Whitecap undertakes no obligation to update such
FOFI. FOFI contained in this press release was made as of the date
of this press release and was provided for the purpose of providing
further information about Whitecap's anticipated future business
operations. Readers are cautioned that the FOFI contained in this
press release should not be used for purposes other than for which
it is disclosed herein.
OIL AND GAS ADVISORIES
Barrel of Oil Equivalency
"Boe" means barrel of oil equivalent. All boe conversions
in this press release are derived by converting gas to oil at the
ratio of six thousand cubic feet ("Mcf") of natural gas to one
barrel ("Bbl") of oil. Boe may be misleading, particularly if used
in isolation. A Boe conversion rate of 1 Bbl : 6 Mcf 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 of oil compared to natural gas
based on currently prevailing prices is significantly different
than the energy equivalency ratio of 1 Bbl : 6 Mcf, utilizing a
conversion ratio of 1 Bbl : 6 Mcf may be misleading as an
indication of value.
Production, Initial Production Rates and Product Type
Information
References to petroleum, crude oil, natural gas liquids
("NGLs"), natural gas and average daily production in this press
release refer to the light and medium crude oil, tight crude oil,
conventional natural gas, shale gas and NGLs product types, as
applicable, as defined in National Instrument 51-101 ("NI
51-101").
NI 51-101 includes condensate within the NGLs product type. The
Company has disclosed condensate as combined with crude oil and
separately from other NGLs since the price of condensate as
compared to other NGLs is currently significantly higher, and the
Company believes that this crude oil and condensate presentation
provides a more accurate description of its operations and results
therefrom. Crude oil therefore refers to light oil, medium oil,
tight oil and condensate. NGLs refers to ethane, propane, butane
and pentane combined. Natural gas refers to conventional natural
gas and shale gas combined.
Any references in this news release to initial production rates
(IP(120), IP(270)) 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. While encouraging, readers are cautioned not to place
reliance on such rates in calculating the aggregate production for
Whitecap.
The Company's average daily production for the three and nine
months ended September 30, 2022 and
2021, the average daily production rate per well for the recent
Kakwa wells (12-33 pad - IP(120); and 14-13 pad - IP(270)), and the
forecast average daily production for the Company for Q4/22, the
full year 2022 and 2023 disclosed in this press release consists of
the following product types, as defined in NI 51-101 and using a
conversion ratio of 1 Bbl : 6 Mcf where applicable:
Initial Production
Rates
|
12-33 IP(120) per
well
|
14-13 IP(270) per
well
|
Light and medium oil
(bbls/d)
|
-
|
-
|
Tight oil/condensate
(bbls/d)
|
575
|
340
|
Crude oil
(bbls/d)
|
575
|
340
|
|
|
|
NGLs
(bbls/d)
|
110
|
140
|
|
|
|
Shale gas
(Mcf/d)
|
7,290
|
7,080
|
Conventional natural
gas (Mcf/d)
|
-
|
-
|
Natural gas
(Mcf/d)
|
7,290
|
7,080
|
|
|
|
Total
(boe/d)
|
1,900
|
1,660
|
Whitecap
Corporate
|
Q4/22
|
2022
|
2023
(mid-point)
|
Light and medium oil
(bbls/d)
|
81,210
|
80,550
|
78,000
|
Tight oil/condensate
(bbls/d)
|
8,750
|
5,400
|
13,500
|
Crude oil
(bbls/d)
|
89,960
|
85,950
|
91,500
|
|
|
|
|
NGLs
(bbls/d)
|
17,625
|
15,555
|
18,500
|
|
|
|
|
Shale gas
(Mcf/d)
|
189,820
|
99,400
|
207,000
|
Conventional natural
gas (Mcf/d)
|
154,668
|
155,570
|
159,000
|
Natural gas
(Mcf/d)
|
344,488
|
254,970
|
366,000
|
|
|
|
|
Total
(boe/d)
|
165,000
|
144,000
|
171,000
|
|
Three months ended
Sep. 30,
|
Nine months ended
Sep. 30,
|
Whitecap
Corporate
|
2022
|
2021
|
2022
|
2021
|
Light and medium oil
(bbls/d)
|
79,180
|
74,722
|
80,328
|
72,727
|
Tight oil/condensate
(bbls/d)
|
5,957
|
2,466
|
4,271
|
1,335
|
Crude oil
(bbls/d)
|
85,137
|
77,188
|
84,599
|
74,063
|
|
|
|
|
|
NGLs
(bbls/d)
|
16,513
|
10,279
|
14,863
|
10,368
|
|
|
|
|
|
Shale gas
(Mcf/d)
|
104,358
|
26,293
|
68,931
|
12,789
|
Conventional natural
gas (Mcf/d)
|
160,528
|
144,514
|
156,145
|
138,190
|
Natural gas
(Mcf/d)
|
264,886
|
170,807
|
225,076
|
150,979
|
|
|
|
|
|
Total
(boe/d)
|
145,798
|
115,935
|
136,975
|
109,594
|
SPECIFIED FINANCIAL MEASURES
This press release includes various specified financial
measures, including non-GAAP financial measures, non-GAAP ratios,
capital management measures and supplementary financial measures as
further described herein. These financial measures are not
standardized financial measures under International Financial
Reporting Standards ("IFRS" or, alternatively, "GAAP") and,
therefore, may not be comparable with the calculation of similar
financial measures disclosed by other companies.
"Free funds flow" is a non-GAAP financial
measure calculated as funds flow less expenditures on
PP&E. Management believes that free funds flow provides a
useful measure of Whitecap's ability to increase returns to
shareholders and to grow the Company's business. Free funds flow is
not a standardized financial measure under IFRS and, therefore, may
not be comparable with the calculation of similar financial
measures disclosed by other entities. The most directly comparable
financial measure to free funds flow disclosed in the Company's
primary financial statements is cash flow from operating
activities. Refer to the "Cash Flow from Operating Activities,
Funds Flow and Payout Ratios" section of our management's
discussion and analysis for the three and nine months ended
September 30, 2022 which is
incorporated herein by reference, and available on SEDAR at
www.sedar.com. In addition, see the following table which
reconciles cash flow from operating activities to funds flow and
free funds flow:
|
Three months ended
Sep. 30,
|
Nine months ended
Sep. 30,
|
($000s)
|
2022
|
2021
|
2022
|
2021
|
Cash flow from
operating activities
|
559,882
|
293,604
|
1,627,211
|
794,730
|
Net change in non-cash
working capital items
|
(13,094)
|
137
|
101,910
|
(46,658)
|
Funds flow
|
546,788
|
293,741
|
1,729,121
|
748,072
|
Expenditures on
PP&E
|
208,004
|
135,204
|
507,529
|
293,486
|
Free funds
flow
|
338,784
|
158,537
|
1,221,592
|
454,586
|
Total payout ratio
(%)
|
50
|
57
|
39
|
50
|
Funds flow per share,
basic
|
0.89
|
0.46
|
2.80
|
1.27
|
Funds flow per share,
diluted
|
0.88
|
0.46
|
2.77
|
1.26
|
"Funds flow", "funds flow basic ($/share)" and "funds
flow diluted ($/share)" are capital management measures and are
key measures of operating performance as they demonstrate
Whitecap's ability to generate the cash necessary to pay dividends,
repay debt, make capital investments, and/or to repurchase common
shares under the Company's NCIB. Management believes that by
excluding the temporary impact of changes in non-cash operating
working capital, funds flow, funds flow basic ($/share) and funds
flow diluted ($/share) provide useful measures of Whitecap's
ability to generate cash that are not subject to short-term
movements in non-cash operating working capital. Whitecap reports
funds flow in total and on a per share basis (basic and diluted),
which is calculated by dividing funds flow by the weighted average
number of basic shares and weighted average number of diluted
shares outstanding for the relevant period. See Note 5(e)(ii)
"Capital Management – Funds Flow" in the Company's unaudited
interim consolidated financial statements for the three and nine
months ended September 30, 2022 for
additional disclosures.
"Net Debt" is a capital management measure that
management considers to be key to assessing the Company's
liquidity. See Note 5(e)(i) "Capital Management – Net Debt and
Total Capitalization" in the Company's unaudited interim
consolidated financial statements for the three and nine months
ended September 30, 2022 for
additional disclosures.
"Operating netback" is a non-GAAP financial measure
determined by adding marketing revenues and processing & other
income, deducting realized losses on commodity risk management
contracts or adding realized gains on commodity risk management
contracts and deducting tariffs, royalties, operating expenses,
transportation expenses and marketing expenses from petroleum and
natural gas revenues. The most directly comparable financial
measure to operating netback disclosed in the Company's primary
financial statements is petroleum and natural gas sales. Operating
netback is a measure used in operational and capital allocation
decisions. Operating netback is not a standardized financial
measure under IFRS and, therefore, may not be comparable with the
calculation of similar financial measures disclosed by other
entities. For further information, refer to the "Operating
Netbacks" section of our management's discussion and analysis for
the three and nine months ended September
30, 2022, which is incorporated herein by reference, and
available on SEDAR at www.sedar.com. A reconciliation of operating
netbacks to petroleum and natural gas revenues is set out
below:
|
Three months ended
Sep. 30,
|
Nine months ended
Sep. 30,
|
Operating Netbacks
($000s)
|
2022
|
2021
|
2022
|
2021
|
Petroleum and natural
gas revenues
|
1,070,509
|
678,115
|
3,336,375
|
1,740,527
|
Tariffs
|
(5,249)
|
(4,576)
|
(16,635)
|
(12,290)
|
Processing & other
income
|
9,876
|
8,852
|
24,107
|
22,978
|
Marketing
revenues
|
80,903
|
45,704
|
224,946
|
106,915
|
Petroleum and natural
gas sales
|
1,156,039
|
728,095
|
3,568,793
|
1,858,130
|
Realized loss on
commodity contracts
|
(29,493)
|
(72,864)
|
(223,587)
|
(153,508)
|
Royalties
|
(218,488)
|
(109,170)
|
(657,573)
|
(271,397)
|
Operating
expenses
|
(199,186)
|
(146,248)
|
(550,043)
|
(407,322)
|
Transportation
expenses
|
(30,455)
|
(24,470)
|
(82,312)
|
(66,759)
|
Marketing
expenses
|
(80,461)
|
(46,036)
|
(223,256)
|
(107,823)
|
Operating
netbacks
|
597,956
|
329,307
|
1,832,022
|
851,321
|
"Operating netback per boe" is a non-GAAP ratio
calculated by dividing operating netbacks by the total production
for the period. Operating netback is a non-GAAP financial measure
component of operating netback per boe. Operating netback per boe
is not a standardized financial measure under IFRS and, therefore
may not be comparable with the calculation of similar financial
measures disclosed by other entities. Presenting operating netback
on a per boe basis allows management to better analyze performance
against prior periods on a comparable basis.
"Production per share" is the Company's total crude oil,
NGL and natural gas production volumes for the applicable period
divided by the weighted average number of diluted shares
outstanding for the applicable period. "Production per share
growth" is determined in comparison to the applicable
comparative period.
"Total payout ratio" is a supplementary financial
measure calculated as dividends paid or declared plus expenditures
on PP&E, divided by funds flow. Management believes that total
payout ratio provides a useful measure of Whitecap's capital
reinvestment and dividend policy, as a percentage of the amount of
funds flow.
Per Share Amounts
Per share amounts noted in this press release are based on fully
diluted shares outstanding.
SOURCE Whitecap Resources Inc.