PetroShale Inc. ("PetroShale" or the "Company") (TSX-V:PSH)
(OTCQX:PSHIF) is pleased to announce its financial and operating
results for the three and twelve month periods ended December 31,
2017, along with updated petroleum reserves as of December 31,
2017.
PetroShale will file its audited consolidated
financial statements and the corresponding Management’s Discussion
and Analysis (“MD&A”) as at and for the year ended December 31,
2017, as well as its 2017 Annual Information Form including its
year end reserves disclosures, on SEDAR at www.sedar.com, on the
OTCQX website at www.otcqx.com, and will post the information on
our website at www.petroshaleinc.com. Copies of the materials
can also be obtained upon request without charge by contacting the
Company directly.
PetroShale continued to focus on acquiring and
developing land in the core of the North Dakota Bakken / Three
Forks play, leading to substantial production and reserves
increases. As announced on April 2, 2018, we acquired
additional acreage in our core South Berthold area for US$17.8
million and generated significant results from recent operated
wells which contributed to average working interest production in
March 2018 of approximately 5,300 barrels of oil equivalent per day
(“boepd”) compared to 2,121 boepd in the fourth quarter of
2017. Our continued operational success and the completion of
a strategic financing in early Q1 2018 have positioned the Company
to further increase production, reserves and our high-quality
drilling inventory as we move forward.
2017 HIGHLIGHTS
- Production averaged 2,121 boepd (86% liquids) in the fourth
quarter, a 14% increase from the fourth quarter of 2016 and a 12%
increase from the third quarter of 2017, largely attributable to
the impact of three (0.6 net) non-operated wells which commenced
production in November 2017.
- Average 2017 production increased by 50% to 2,445 boepd (88%
liquids), from 1,631 boepd (83% liquids) in 2016.
- Revenue in 2017 was $44.0 million, an increase of 89% over
2016.
- EBITDA in 2017 was $21.2 million, an increase of 123% over
2016.
- The operating netback in 2017 was $27.46 per boe (Company
interest, gross of royalty; $34.65 per boe net of royalty), an
increase of 36% over 2016.
- The average differential between PetroShale’s realized crude
oil price and WTI continued to narrow during 2017 to an average of
US$2.46 per Bbl in the fourth quarter, down from US$6.21 per Bbl in
the fourth quarter of 2016 and US$5.14 per Bbl in the third quarter
of 2017, largely due to increased takeaway capacity on the Dakota
Access Pipeline.
- Capital expenditures during 2017 of $67.1 million were directed
to drilling and completion activities plus several
acquisitions. One of these acquisitions included the addition
of undeveloped acreage in a core focus area, providing us
operatorship of a second drilling spacing unit (“DSU”) (“Horse
Camp”).
- Drilling of two (1.7 net) wells continued during the fourth
quarter of 2017 on PetroShale’s first operated DSU in the Antelope
area (“Primus”) and two additional operated wells (100% working
interest) in the South Berthold area on our Horse Camp DSU, with
all four wells being placed into production at various times during
the first quarter of 2018.
- Oil and natural gas reserve volumes and related net present
value (discounted at 10% - “NPV10”) increased across all categories
at year end 2017 compared to the prior year:
- Total proved plus probable (“P+P”) reserves increased 17% to
36.7 million boe (“Mmboe”), from 31.5 Mmboe.
- NPV10 of the P+P reserves increased 23% to US$493.0 million,
from US$399.5 million, despite continued volatility and uncertainty
in forward commodity prices.
- A common share equity offering that netted $106 million in
proceeds closed in April 2017 and significantly improved
PetroShale’s financial flexibility.
Recent Developments
- PetroShale completed four gross (3.7 net) operated wells,
resulting in average production of approximately 5,300 boepd of
production in March, an increase of approximately 150% over the
fourth quarter of 2017.
- PetroShale closed US$17.8 million of undrilled acreage
additions in its core South Berthold focus area.
- A strategic financing with a US-based private equity investor,
First Reserve, closed in January 2018 for US$75 million of
preferred shares with a 5-year term and a 9% coupon rate. The
preferred shares are fully exchangeable into common shares at $2.40
per share. Proceeds were used to repay and terminate the
Company’s subordinated loan facility and repay amounts drawn under
the senior loan. Brooks Shughart, a Managing Director of
First Reserve with significant energy experience, joined
PetroShale’s board.
- The capacity of the Company’s senior loan was increased to
US$49.9 million in April 2018 following the recent production
increase.
RESULTS OF OIL AND GAS ACTIVITIES
|
|
Three months ended |
|
|
Twelve months ended |
|
|
|
December 31, 2017 |
|
|
December 31, 2016 |
|
|
December 31, 2017 |
|
|
December 31, 2016 |
|
Sales volumes |
|
|
|
|
Crude Oil
(Bbl/d) |
|
1,554 |
|
|
1,325 |
|
|
1,878 |
|
|
1,221 |
|
Natural gas and NGLs (Mcf/d) |
|
3,398 |
|
|
3,218 |
|
|
3,401 |
|
|
2,458 |
|
Barrel of oil
equivalent (Boe/d) |
|
2,121 |
|
|
1,861 |
|
|
2,445 |
|
|
1,631 |
|
|
|
|
|
|
Operating Netbacks ($/Boe) (1) |
|
|
|
|
Revenue |
$ |
54.18 |
|
$ |
44.67 |
|
$ |
49.27 |
|
$ |
38.95 |
|
Royalties |
|
(11.03 |
) |
|
(9.39 |
) |
|
(10.19 |
) |
|
(7.99 |
) |
Operating
costs |
|
(8.01 |
) |
|
(7.63 |
) |
|
(7.97 |
) |
|
(7.86 |
) |
Production
taxes |
|
(3.97 |
) |
|
(3.30 |
) |
|
(3.65 |
) |
|
(2.96 |
) |
Operating netback(2) |
$ |
31.17 |
|
$ |
24.35 |
|
$ |
27.46 |
|
$ |
20.14 |
|
Operating
netback, on a net of royalty basis(2) |
$ |
39.11 |
|
$ |
30.86 |
|
$ |
34.65 |
|
$ |
25.34 |
|
(1) See "Oil and Gas
Advisories".(2) See “Non-GAAP Measures”.
2017 YEAR-END RESERVES
The reserves data in this press release is based
upon an evaluation by Netherland, Sewell & Associates, Inc.
(“NSAI”) with an effective date of December 31, 2017. The
reserves data summarizes PetroShale’s crude oil and natural gas
reserves and the net present value of future net revenue for these
reserves using forecast prices and costs. All references to
reserves are to gross Company reserves, meaning PetroShale’s
working interest reserves before consideration of royalty
interests. The reserve report has been prepared in accordance with
the standards contained in the COGE Handbook and the reserve
definitions contained in National Instrument 51‑101 (“NI 51-101”)
and CSA Staff Notice 51‑324. No attempt was made to evaluate
possible reserves.
2017 Reserves Highlights
- Total proved (“TP”) reserves increased by 22% to 30.6 Mmboe
(US$427.0 million PV10) and P+P reserves increased by 17% to 36.7
Mmboe (US$493.0 million PV10) from 2016;
- P+P finding, development and acquisition costs (“FD&A”)
were $20.30 per boe for 2017 (year ended December 31, 2016 - $9.17
per boe) (including changes in future development capital) and
total proved FD&A was $20.08 per boe for 2017 (year ended
December 31, 2016 - $10.89 per boe);
- The three year average P+P FD&A and finding and development
costs (“F&D”) costs were $11.87 per boe and $16.89 per boe,
respectively;
- Based on the Company’s fourth quarter of 2017 operating netback
of $31.17 per boe, FD&A recycle ratios for P+P and TP were 1.5
and 1.6 times, respectively. The three year average
FD&A recycle ratio was 2.6 and 2.5 times for P+P and TP,
respectively;
- P+P Reserve Life Index (“RLI”) totaled 47.5 years, reflecting
annualized fourth quarter of 2017 average production of 2,121
boepd. Using the Company’s estimated March 2018 production,
the P+P RLI would be approximately 19 years; and
- Our P+P F&D costs for 2017 were higher than the three year
average due to a combination of factors, including larger fracs
than initially planned on the Horse Camp wells and extreme winter
weather in North Dakota that led to higher frac water heating
costs, increased downtime and overall higher costs for our new
operated wells as well as the costs associated with the workover of
the Primus “8H” well. Each of our operated wells also bore 100% of
the cost of new roads, pads and facilities and are expected to
result in lower construction costs for future wells that will be
drilled from these pads. On the positive side, all of the new wells
are performing at or above our internal type curves and estimates
that are reflected in the NSAI reserve evaluation.
Gross Company Interest Reserves
|
Reserves |
|
Tight Oil |
Shale Gas (2) |
BOE |
|
Gross |
Net |
Gross |
Net |
Gross |
Net |
Reserves Category |
(Mbbl) |
(Mbbl) |
(Mmcf) |
(Mmcf) |
(Mboe) |
(Mboe) |
PROVED: |
|
|
|
|
|
|
|
Developed
Producing |
4,324.3 |
3,445.3 |
7,202.5 |
5,706.3 |
5,524.7 |
4,396.4 |
|
Developed
Non-Producing |
0.4 |
0.3 |
0.9 |
0.7 |
0.6 |
0.4 |
|
Undeveloped |
21,263.9 |
17,039.9 |
22,879.7 |
18,294.5 |
25,077.2 |
20,089.0 |
TOTAL
PROVED |
25,588.6 |
20,485.6 |
30,083.1 |
24,001.5 |
30,602.5 |
24,485.8 |
PROBABLE |
5,180.2 |
4,115.5 |
5,726.1 |
4,545.5 |
6,134.6 |
4,873.1 |
TOTAL PROVED PLUS PROBABLE |
30,768.8 |
24,601.1 |
35,809.2 |
28,547.0 |
36,737.0 |
29,358.8 |
Notes: (1) Columns may not add due to rounding.
(2) All of our shale gas reserves represent solution gas associated
with our tight oil reserves.
Net Present Value of Future Net Revenue ($
US)
|
Before Income Taxes Discounted at
(%/year) |
|
0% |
|
5% |
|
10% |
|
15% |
|
20% |
|
Reserves Category |
($US 000s) |
|
($US 000s) |
|
($US 000s) |
|
($US 000s) |
|
($US 000s) |
|
PROVED: |
|
|
|
|
|
|
Developed
Producing |
172,209.8 |
|
120,064.1 |
|
92,538.8 |
|
75,947.0 |
|
64,947.3 |
|
|
Developed
Non-Producing |
(4.4 |
) |
(3.9 |
) |
(3.6 |
) |
(3.3 |
) |
(3.0 |
) |
|
Undeveloped |
782,755.4 |
|
487,142.5 |
|
334,467.5 |
|
244,155.3 |
|
185,430.9 |
|
TOTAL
PROVED |
954,960.8 |
|
607,202.7 |
|
427,002.8 |
|
320,099.1 |
|
250,375.2 |
|
PROBABLE |
169,594.1 |
|
101,903.1 |
|
65,986.8 |
|
44,771.3 |
|
31,237.4 |
|
TOTAL PROVED PLUS PROBABLE |
1,124,555.0 |
|
709,105.8 |
|
492,989.6 |
|
364,870.4 |
|
281,612.6 |
|
Notes: (1) Columns may not add due to
rounding
As a reporting issuer in Canada, PetroShale is
required to report its reserves and NPV10 using forecast pricing
and costs, as stipulated under NI 51-101. The forecast prices
reflected in the NPV10 is included in our 2017 Annual Information
Form, expected to be filed on SEDAR before the end of April,
2018.
Reserves Reconciliation
|
Total (Mboe) |
|
Total Proved |
|
Probable |
|
Total Proved PlusProbable |
|
December 31, 2016 |
25,134.0 |
|
6,316.3 |
|
31,450.3 |
|
Discoveries |
- |
|
- |
|
- |
|
Extensions and
Improved Recovery |
- |
|
- |
|
- |
|
Technical
Revisions (1) |
435.0 |
|
45.5 |
|
480.4 |
|
Acquisitions
(2) |
5,688.9 |
|
- |
|
5,688.9 |
|
Dispositions |
- |
|
- |
|
- |
|
Economic
Factors |
237.1 |
|
(227.2 |
) |
9.9 |
|
Production
(3) |
(892.5 |
) |
- |
|
(892.5 |
) |
December 31, 2017 |
30,602.5 |
|
6,134.6 |
|
36,737.0 |
|
Notes: (1) Technical revisions include
additional well locations assigned proved undeveloped and probable
reserves as well as increased proved and probable reserve
assignments to well locations included in the December 31, 2016
reserve report. These revisions are based on additional
technical information gathered in 2017 from analogous wells drilled
and completed near our lands and increases in the number of wells
planned by operators on our lands. (2) The acquisitions amount
is the estimate of reserves at December 31, 2017. (3) Columns
may not add due to rounding.
2017 Capital Program Efficiency
|
Finding, Development & Acquisition
(“FD&A”)(1) |
Finding & Development
(“F&D”)(1) |
|
Total Proved |
Proved plusProbable |
Total Proved |
Provedplus Probable |
Capital Costs
($000s): |
|
|
|
|
Acquisitions |
|
15,897 |
|
15,897 |
|
|
Dispositions |
|
- |
|
- |
|
|
Capital
expenditures |
|
51,121 |
|
51,121 |
|
51,121 |
|
|
51,121 |
|
Change in future development capital |
|
60,697 |
|
58,393 |
|
(17,992 |
) |
|
(17,992 |
) |
Total
FD&A / F&D Costs |
|
127,715 |
|
125,411 |
|
33,129 |
|
|
33,129 |
|
|
|
|
|
|
Reserves
additions (Mboe) |
|
|
|
|
Net change in
reserve volumes |
|
5,469 |
|
5,287 |
|
5,469 |
|
|
5,287 |
|
Add back
production |
|
893 |
|
893 |
|
893 |
|
|
893 |
|
Reserves
associated with acquisitions |
|
- |
|
- |
|
(5,689 |
) |
|
(5,689 |
) |
Reserves associated with dispositions |
|
- |
|
- |
|
- |
|
|
- |
|
Total
additions |
|
6,361 |
|
6,179 |
|
672 |
|
|
490 |
|
FD&A and
F&D Costs ($/boe) |
$ |
20.08 |
$ |
20.30 |
$ |
49.27 |
|
$ |
67.60 |
|
Three Year FD&A and F&D Costs ($/boe)
(3) |
$ |
12.62 |
$ |
11.87 |
$ |
17.71 |
|
$ |
16.89 |
|
Recycle
Ratio (2) |
|
1.6 |
|
1.5 |
|
0.6 |
|
|
0.5 |
|
Three Year Recycle Ratio (4) |
|
2.5 |
|
2.6 |
|
1.8 |
|
|
1.8 |
|
Notes: (1) The calculation of F&D and
FD&A costs incorporates the change in future development
capital (“FDC”) required to bring proved undeveloped and probable
reserves into production. In all cases, the F&D or
FD&A number is calculated by dividing the identified capital
expenditures, after changes in FDC, by the applicable reserves
additions. We have disclosed both finding and development
costs and finding, development and acquisition costs because
acquisition costs have been a significant component of our total
capital expenditures and strategy, and also due to the difficulty
in allocating changes in future development costs between reserve
additions from drilling, technical revisions and
acquisitions. For purposes of calculating finding and
development costs, we have chosen to reflect the change in future
development costs associated with drilling activity during the
period and exclude the increase in future development costs
associated with acquisitions during the year. (2) Recycle
ratio is defined as operating netback, for the fourth quarter of
2017, divided by F&D or FD&A costs, as applicable, on a per
boe basis. Operating netback is calculated as revenue
(including realized hedging gains and losses) minus royalties,
operating costs and production taxes. PetroShale’s operating
netback in the fourth quarter of 2017 averaged $31.17 per
boe. (3) The calculation of the three year FD&A and
F&D costs reflect the sum of the capital costs and net reserve
additions for the years ended 2015 through 2017. (4) The
calculation of the three year recycle ratio reflects the operating
netback for the fourth quarter of 2017, divided by the three year
F&D or FD&A costs, as applicable, on a per boe
basis.
Net
Asset Value (“NAV”) per Share as at December 31, 2017 |
|
|
($
thousands, except share and per share amounts) |
|
|
|
|
|
|
|
|
Proved Plus
Probable Reserve Value (NPV10 Before Tax) |
$ 618,702 |
|
|
Undeveloped Land Value |
|
6,802 |
|
|
Net Debt (including Decommissioning Obligation)(2) |
|
(95,617 |
) |
|
Total Net Assets |
|
|
$ 529,887 |
|
|
Common Shares
Outstanding |
|
|
|
157,137,767 |
|
|
Estimated Net Asset Value per Basic Common
Share(1) |
$ 3.37 |
|
Notes: (1) Net asset value is calculated as at a
particular date and is, by its nature, historical, and may not be
reflective of PetroShale's future performance. The NAV
Reflects the NPV10 of the Company’s reserves at an exchange rate of
US$1.00 = Cdn$1.26. (2) See “Non-GAAP Measures”.
MESSAGE FROM THE CEO
2017 was a year in which PetroShale established
itself as an operator within the core of the prolific North Dakota
Bakken / Three Forks play. In 2017, we increased our acreage
position through a number of acquisitions totalling $15.9 million
and participated in 94 gross (7.0 net) operated and non-operated
wells. The Company’s activity contributed to average annual
production volumes of 2,445 boe/d, an increase of 50% over the
prior year.
Subsequent to year end, we announced the results
of four (3.7 net) operated wells on our Primus and Horse Camp DSUs
that were brought on line during the first quarter of 2018.
These wells had a material impact with net production
increasing to an estimated 5,300 boe/d in March of 2018. At
the end of the second quarter we also anticipate production from
four (1.6 net) new non‐operated wells on the “Packineau” DSU. In
addition, by the end of the second quarter, all of our new operated
wells will have been tied-in to natural gas gathering pipelines
which will also positively impact our production volumes going
forward.
Although crude oil prices have remained
volatile, both WTI benchmark prices and differentials improved
during the fourth quarter. The commencement of operations of
the Dakota Access Pipeline, which significantly enhances takeaway
capacity from the Bakken to the Gulf Coast and other markets,
contributed to stronger realized pricing and helped to slightly
offset a lower US$ / CAD$ exchange rate. Realized natural gas
yields have increased relative to 2016 as a larger percentage of
our gas production is processed into natural gas liquids (“NGLs”),
the pricing of which has improved in lock-step with crude oil.
Our year end 2017 reserves evaluation reflects
the impact of acquisition activity as well as our robust drilling
and completions program. We successfully recorded reserves
volume and value increases across all categories. Our P+P
reserves increased 17% to 36.7 Mmboe, from 31.5 Mmboe at December
31, 2016, while our P+P NPV10 increased 23% to US$493.0
million. On a TP basis, reserves increased 22% to 30.6 Mmboe
with a 28% increase in NPV10 to $427.0 million. We achieved
this growth responsibly, with P+P FD&A costs averaging $20.30
per boe (including changes in future development capital),
generating a P+P recycle ratio of 1.5 times.
Maintaining ample liquidity and access to
capital has remained a priority for PetroShale as we continue to
grow and increase our number of operated DSUs. In the second
quarter of 2017, we successfully closed a $110 million equity
offering and increased our borrowing capacity to US$39.9 million
under our senior credit facility, all of which gave us substantial
undrawn credit capacity. Early in 2018, we further enhanced
our financial position through a strategic US$75 million placement
of preferred shares with First Reserve, a US-based energy-focused
private equity firm. This transaction enabled us to repay all
amounts owing under the subordinated credit facility and senior
credit facility. With this transaction, PetroShale can pursue
future potential land acquisitions and fund our attractive drilling
opportunities.
The quality of PetroShale’s asset base and our
ability to generate compelling economics during a period of
continued oil price recovery was demonstrated by stronger
performance in 2017 relative to 2016. With a 2017 operating
netback of $27.46 per boe ($34.65 per boe on a net of royalty
basis) and higher production volumes, we grew EBITDA by 123% over
2016 to $21.2 million. We anticipate that improving oil
prices and lower fixed operating costs per BOE, following recent
increases in production, will contribute to further netback
improvements in 2018.
PetroShale’s ongoing evolution and growth have
set the stage to generate per share growth in production, reserves
and EBITDA. We continue to seek opportunities to enhance our
high-quality asset base within or adjacent to our core areas and
look forward to further results as we continue to develop our
lands. In 2018, we plan to drill approximately 7 to 8 net
wells of which 5 to 6 net wells will be operated. It is
anticipated that the drilling program will commence in the third
quarter of 2018 and continue into the first quarter of 2019 with
completion and tie-in operations.
I would like to thank all of PetroShale’s
employees, directors and shareholders for your continued support of
our strategy and our Company, and we look forward to updating you
on our progress and achievements through the balance of 2018.
((signed))
Mike WoodPresident & CEO
About PetroShale
PetroShale is an oil company engaged in the
acquisition, development and consolidation of interests in the
North Dakota Bakken / Three Forks.
For more information, please
contact:
PetroShale Inc.Attention: President and CEOEmail:
Info@PetroShaleInc.comPhone:
+1.303.297.1407www.petroshaleinc.com
or
Cindy Gray5 Quarters Investor Relations, Inc.403.828.0146
or info@5qir.com
Neither the TSX Venture Exchange nor its
Regulation Services Provider (as that term is defined in the
policies of the TSX Venture Exchange) accepts responsibility for
the adequacy or accuracy of this release.
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, among other things, available aspects
of management focus, objectives, strategies and business
opportunities. More particularly and without limitation, this press
release contains forward-looking information concerning: the
opportunity to use available and undrawn amounts under the
Company's credit facilities to fund drilling and acquisitions,
PetroShale's position to achieve future growth in production,
reserves and revenue; PetroShale's intention to seek out land
acquisition opportunities; the sufficiency of the Company's
financial flexibility and capital requirements; the Company's
growth and development plans, including anticipated new well
production; the anticipated benefits to the Company from
certain infrastructure investments on its properties; the Company's
participation in drilling opportunities and the future prospects
for new wells (including with respect to the Company’s planned 2018
drilling program); anticipated connection of new wells to gas
gathering infrastructure; the impact of recent pipeline development
on future oil price differentials; anticipated production increases
and associated netback increases; and the general outlook of the
Company. PetroShale provided such forward-looking statements in
reliance on certain expectations and assumptions that it
believes are reasonable at the time, including expectations and
assumptions concerning prevailing commodity prices, liquidity,
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 volumes; business
prospects and opportunities; the availability and cost of
financing, labor and services; the impact of increasing
competition; ability to market oil and natural gas successfully;
and the Company's ability to access capital.
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.
Although the Company believes 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 the Company can
give no assurance that they will prove to be correct.
Forward-looking information addresses future events and conditions,
which by their very nature involve inherent risks and
uncertainties. The Company's 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 the Company 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 the Company's 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 the Company disclaims 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:
Within this press release, references are made
to “NAV”, “operating netback”, “operating netback on a net of
royalty basis”, “net debt” and “EBITDA”, which are not recognized
measures under IFRS and therefore may not be comparable to
performance measures presented by others. EBITDA means net
income (loss) before taxes, depletion and depreciation expense,
exploration and evaluation expense, any impairments, finance
expense, any gain or loss on property dispositions, foreign
exchange gain or loss, share-based compensation expense and
unrealized gain or loss on financial derivatives.
Operating netback means revenue less royalties, production taxes
and operating costs and has been presented on a per Boe
basis. Operating netback on a net of royalty basis represents
operating netback divided by production, net of royalty
interests. Net debt represents total liabilities less current
assets. NAV means net asset value, which is the NPV10 before
tax of the Company’s proved plus probable reserves, less net
debt. Management believes that in addition to net income
(loss) and cash flow from (used in) operating activities, EBITDA
and operating netback are useful supplemental measures as they
assist a reader in the determination of the Company's operating
performance, leverage and liquidity. Management believes NAV or net
asset value is a useful measure as it assists the reader in
determining the Company’s value per share. Readers are
cautioned, however, that these measures should not be construed as
an alternative to net income (loss) or cash flow from (used in)
operating activities and consolidated assets as determined in
accordance with IFRS as an indication of our performance or
value.
Oil and Gas Advisories:
This press release contains certain oil and gas
metrics such as "finding and development costs" (or F&D),
"finding development and acquisition costs" (or FD&A), "Recycle
Ratio", and "Reserve Life Index", which do not have standardized
meanings or standard methods of calculation and therefore such
measures may not be comparable to similar measures used by other
companies and should not be used to make comparisons. Such
metrics have been included in this document to provide readers with
additional measures to evaluate the performance of our oil and gas
activities however, such measures are not reliable indicators of
our future performance and future performance may not compare to
our performance in previous periods and therefore such metrics
should not be unduly relied upon. We have disclosed both
finding and development costs and finding, development and
acquisition costs as measures in this press release because
acquisition costs have been a significant component of our total
capital expenditures and strategy, and also due to the difficulty
in allocating changes in future development costs between reserve
additions from drilling, technical revisions and
acquisitions. We believe both measures are useful
measures for readers to determine the efficiency of our acquisition
and development program. Recycle Ratio is defined as
operating netback divided by F&D or FD&A costs, as
applicable, on a per boe basis. Management uses this measure as an
indicator of profitability of its oil and gas activities. Reserves
Life Index is calculated as total company share reserves divided by
annualized current production. Management uses this measure to
determine how long the booked reserves will last at current
production rates if no further reserves were added.
Where amounts are expressed on a barrel of oil
equivalent (“Boe”) basis, natural gas volumes have been converted
to Boe using a ratio of 6,000 cubic feet of natural gas to one
barrel of oil (6 Mcf: 1 Bbl). This Boe conversion
ratio 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 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 Mcf: 1
Bbl, utilizing a conversion ratio at 6 Mcf: 1 Bbl may be misleading
as an indication of value. In this release, mboe refers to
thousands of barrels of oil equivalent, while mbbls refers to
thousands of barrels of oil, and mmcf refers to millions of cubic
feet of natural gas.
All dollar figures included herein are
presented in Canadian dollars, unless otherwise
noted.
Petroshale (TSXV:PSH)
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Petroshale (TSXV:PSH)
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から 12 2023 まで 12 2024