FOR: KELT EXPLORATION LTD.
TSX Symbol: KEL
Date issue: November 09, 2017
Time in: 9:00 AM e
Attention:
CALGARY, AB –(Marketwired – November 09, 2017) – Kelt Exploration Ltd. (TSX:
KEL) (“Kelt” or the “Company”) has released its financial and operating
results for the three and nine months ended September 30, 2017. The Company’s
financial results are summarized as follows:
/T/
—————————————————————————-
Three months ended Nine months ended
FINANCIAL HIGHLIGHTS September 30 September 30
(CA$ thousands, except
as otherwise indicated) 2017 2016 % 2017 2016 %
—————————————————————————-
Revenue, before
royalties and financial
instruments 56,422 47,760 18 176,719 128,876 37
Adjusted funds from
operations (1) 22,957 17,658 30 75,113 35,280 113
Basic ($/ common
share) (1) 0.13 0.10 30 0.43 0.20 115
Diluted ($/ common
share) (1) 0.13 0.10 30 0.42 0.20 110
Loss and comprehensive
loss (10,653) (15,299) -30 (17,789) (61,630) -71
Basic ($/ common
share) (0.06) (0.09) -33 (0.10) (0.36) -72
Diluted ($/ common
share) (0.06) (0.09) -33 (0.10) (0.36) -72
Total capital
expenditures, net of
dispositions 75,933 12,616 502 72,199 61,929 17
Total assets 1,227,962 1,232,147 0 1,227,962 1,232,147 0
Bank debt, net of
working capital (1) 134,759 132,471 2 134,759 132,471 2
Convertible debentures 73,584 70,134 5 73,584 70,134 5
Shareholders’ equity 830,344 823,887 1 830,344 823,887 1
Weighted average shares
outstanding (000s)
Basic 176,013 174,349 1 175,875 172,338 2
Diluted 177,206 174,671 1 177,204 172,585 3
—————————————————————————-
/T/
(1) Refer to advisories regarding non-GAAP financial measures and other key
performance indicators.
Financial Statements
Kelt’s unaudited consolidated interim financial statements and related notes
for the quarter ended September 30, 2017 will be available to the public on
SEDAR at www.sedar.com and will also be posted on the Company’s website at
www.keltexploration.com on November 9, 2017.
Kelt’s operating results for the third quarter ended September 30, 2017 are
summarized as follows:
/T/
—————————————————————————-
Three months ended Nine months ended
OPERATIONAL HIGHLIGHTS September 30 September 30
(CA$ thousands, except
as otherwise
indicated) 2017 2016 % 2017 2016 %
—————————————————————————-
Average daily
production
Oil (bbls/d) 6,881 4,606 49 6,206 5,179 20
NGLs (bbls/d) 2,714 2,960 -8 2,348 2,778 -15
Gas (mcf/d) 77,489 77,854 0 75,524 80,327 -6
—————————————————————————-
Combined (BOE/d) 22,510 20,542 10 21,141 21,345 -1
—————————————————————————-
Production per million
common shares (BOE/d)
(1) 128 118 8 120 124 -3
Average realized
prices, before
financial instruments
Oil ($/bbl) 53.22 52.47 1 56.51 44.64 27
NGLs ($/bbl) 24.34 17.96 36 26.79 16.82 59
Gas ($/mcf) 2.33 2.88 -19 3.09 2.39 29
Operating netbacks
($/BOE) (1)
Petroleum and
natural gas revenue 27.24 25.27 8 30.62 22.04 39
Cash premiums on
derivatives – 0.13 -100 – 0.04 -100
Realized gain (loss)
on financial
instruments 0.02 0.07 -71 (0.06) 0.02 -400
—————————————————————————-
Average realized
price, after
financial
instruments 27.26 25.47 7 30.56 22.10 38
Royalties (2.46) (2.55) -4 (2.84) (1.83) 55
Production expense (9.19) (8.43) 9 (9.67) (9.23) 5
Transportation
expense (2.75) (2.76) 0 (3.14) (2.78) 13
—————————————————————————-
Operating netback
(1) 12.86 11.73 10 14.91 8.26 81
—————————————————————————-
Undeveloped land
Gross acres 775,485 717,641 8 775,485 717,641 8
Net acres 657,175 596,957 10 657,175 596,957 10
—————————————————————————-
/T/
(1) Refer to advisories regarding non-GAAP financial measures and other key
performance indicators.
Message to Shareholders
Average production for the three months ended September 30, 2017 was 22,510
BOE per day, up 9% compared to average production of 20,684 BOE per day during
the previous quarter ended June 30, 2017 and up 10% compared to average
production of 20,542 BOE per day during the quarter ended September 30, 2016.
Year-over-year, Kelt’s oil production has increased significantly, averaging
6,881 barrels per day during the third quarter of 2017, up 49% from average
oil production of 4,606 barrels per day in the third quarter of 2016.
Kelt expects to exit 2017 with approximately 27,500 BOE per day of estimated
production, up 4% from its previous estimate of 26,500 BOE per day. Estimated
exit production (average production for the month of December) does not
include eight wells that are expected to be drilled in 2017 and put on
production in 2018. These include a five-well pad at Pouce Coupe targeting
Montney Oil and three wells at Inga âÇô two of which are targeting the Upper
Montney and the third of which is targeting the Middle Montney. Average
production for 2017 is estimated to be 21,800 BOE per day (previous forecast
was 22,500 BOE per day) and is estimated to be weighted 42% to oil and NGLs
and 58% to gas. The reduction in forecasted 2017 production reflects the
previously announced shut-in of approximately 4,770 BOE (92% gas) per day in
both Alberta and British Columbia due to low domestic gas prices. The majority
of this production was brought back on-stream in early November to coincide
with the start of Kelt’s new gas contracts outside of the AECO and Station 2
Gas Hubs.
Kelt’s realized average oil price during the third quarter of 2017 was $53.22
per barrel, up 1% from $52.47 per barrel in the third quarter of 2016. The
realized average NGLs price during the third quarter of 2017 was $24.34 per
barrel, up 36% from $17.96 per barrel in the corresponding quarter of 2016.
Kelt’s realized average gas price for the third quarter of 2017 was $2.33 per
MCF, down 19% from $2.88 per MCF in the third quarter of the previous year.
For the three months ended September 30, 2017, revenue was $56.4 million and
adjusted funds from operations was $23.0 million ($0.13 per share, diluted),
compared to $47.8 million and $17.7 million ($0.10 per share, diluted)
respectively, in the third quarter of 2016. At September 30, 2017, bank debt,
net of working capital was $134.8 million, up 2% from $132.5 million at
September 30, 2016.
Capital expenditures incurred during the three months ended September 30, 2017
were $75.9 million. The Company spent $45.7 million (60%) on drilling and
completion operations, $24.6 million (33%) on facilities, pipelines and
equipment and $5.6 million (7%) on land and seismic.
Positive indicators have started to appear that may lead to higher oil and gas
prices in 2018:
/T/
— U.S. crude oil exports increased substantially in October 2017 and U.S.
crude oil inventories continue to decline;
— The Brent-WTI crude oil price differential in October 2017 has widened,
potentially implying that global crude oil supply/demand has tightened;
— U.S. natural gas exports (to Mexico and LNG) continue to grow; and
— U.S. natural gas storage at the end of the winter withdrawal season in
2016 has gone from a 1.0 tcf surplus compared to the previous year to
current gas storage that is below the comparative period of the previous
year.
/T/
Kelt is forecasting WTI crude oil to average US$52.00 per barrel in 2018, up
4% from the estimated average price of US$50.00 per barrel in 2017. AECO
natural gas prices are forecasted to average $2.15 per GJ in 2017, unchanged
from the Company’s estimated average AECO price in 2017. Kelt is expecting to
realize a premium (prior to adjusting for heat content) of approximately 30%
to the average forecasted AECO price in 2018 as a result of its diversified
portfolio of gas marketing contracts.
Kelt has prepared its 2018 budget based on capital expenditures of $210.0
million and with management’s forecasted commodity prices the following
results are projected:
/T/
— Estimated average production of 28,500 to 29,500 BOE per day;
— Production mix is expected to be weighted 47% to oil/NGLs and 53% to
gas;
— Operating income is expected to be derived 83% from oil/NGLs and 17%
from gas;
— Estimated funds from operations of $175.0 million ($0.97 per share,
diluted); and
— Estimated bank debt, net of working capital as at December 31, 2018 of
$155.0 million (0.9 times forecasted 2018 funds from operations).
/T/
Kelt is currently unhedged in 2018. As a result, a 10% change in the Company’s
forecasted average oil/NGLs price for 2018 would change forecasted funds from
operations by approximately $21.0 million. A 10% change in the Company’s
average gas price forecasted for 2018 would impact funds from operations by
approximately $11.0 million.
The Company is well positioned financially to execute its budgeted capital
program during 2018, leading into the year with strong operational momentum.
Management looks forward to updating shareholders with 2017 fourth quarter and
year-end results on or about March 7, 2018.
Flow-Through Equity Financing
In October 2017, the Company completed non-brokered private placements of 2.6
million common shares for aggregate gross proceeds of $20.6 million, of which:
2.0 million common shares were issued on a “flow-through” basis in respect of
Canadian Development Expenses (“CDE”) at a price of $7.75 per share for gross
proceeds of $15.6 million; and 0.6 million common shares were issued on a
“flow-through” basis in respect of Canadian Exploration Expenses (“CEE”) at a
price of $8.75 per share for gross proceeds of $5.0 million (together, the
“Private Placements”). After estimated expenses related to the Private
Placements, net proceeds to Kelt were approximately $20.3 million.
Proceeds from the CDE private placement will be used to partially finance the
Company’s development drilling and completion expenditures during the
remainder of 2017. Pursuant to the provisions in the Income Tax Act (Canada),
Kelt will incur eligible CDE prior to December 31, 2017, in the aggregate
amount of not less than the total gross proceeds of the CDE private placement
of $15.6 million.
Proceeds from the CEE private placement will be used to partially finance the
Company’s exploration drilling and completion expenditures in 2018. Pursuant
to the “look-back” provisions in the Income Tax Act (Canada), Kelt will incur
eligible CEE prior to December 31, 2018, in the aggregate amount of not less
than the total gross proceeds of the CEE private placement of $5.0 million.
The qualifying expenditures to be incurred will be renounced to the
subscribers with an effective date of December 31, 2017.
The common shares issued in connection with the Private Placements are subject
to a statutory hold period of four months plus one day from the respective
dates of closing of the Private Placements, in accordance with applicable
securities legislation.
Outlook and Guidance
During the period of low oil and gas prices experienced by the energy
industry, Kelt was well positioned to take advantage of opportunities to add
value at a reasonable cost. The cost to acquire land at Crown sales in the
Company’s core operating areas had dropped significantly and service related
costs to drill and complete wells had also declined substantially. Kelt has
transitioned to development pad drilling in order to take advantage of lower
oilfield related service costs and will continue to test newly acquired
exploration lands.
2017 Outlook
WTI crude oil prices are forecasted to average US$50.00 per barrel in 2017 (no
change from previous forecast), up 15% from the average price of US$43.32 per
barrel in 2016. AECO natural gas prices are forecasted to average $2.15 per GJ
in 2017 (down 14% from the previous forecast of $2.50 per GJ), up 5% from the
average price of $2.05 per GJ in 2016.
The Company’s Board of Directors has increased Kelt’s 2017 capital
expenditures budget to $226.0 million ($115.0 million net after dispositions),
up 12% from its previous budget of $202.0 million ($91.0 million net after
dispositions). The increase will allow the Company to move certain drilling
projects, originally planned for the first quarter of 2018, forward to the
fourth quarter of 2017, giving Kelt the ability to take advantage of
favourable service costs that could potentially be higher in the first quarter
of 2018. The increased budget includes $15.6 million of development drilling
and completion capital expenditures that the Company has committed to incur
prior to December 31, 2017, pursuant to the CDE flow-through private
placement.
Forecasted average production of 21,800 BOE per day in 2017 (previous forecast
was 22,500 BOE per day) represents a 4% increase from average production of
20,947 BOE per day in 2016 and is estimated to be weighted 42% to oil/NGLs and
58% to gas. The reduction in forecasted 2017 production reflects the
previously announced shut-in of approximately 4,770 BOE (92% gas) per day in
both Alberta and British Columbia due to low domestic gas prices. The majority
of this production was brought back on-stream in early November to coincide
with the start of Kelt’s new gas contracts outside of the AECO and Station 2
Gas Hubs.
After giving effect to the aforementioned production estimates, commodity
price assumptions and estimated expenses, funds from operations for 2017 is
forecasted to be approximately $110.0 million (previous forecast was $124.0
million) or $0.62 (previous forecast was $0.70) per common share, diluted.
Kelt estimates that the Company’s bank debt, net of working capital, will be
approximately $120.0 million as at December 31, 2017 (previous forecast was
$104.0 million). Bank debt, net of working capital at December 31, 2017 is
estimated to be 1.1 times forecasted 2017 funds from operations. Royalties are
expected to average 9.9% of revenue in 2017 (previous forecast was 10.2%). On
average during 2017, combined production and transportation expense is
estimated to be $12.74 per BOE (previous forecast was $12.61 per BOE), G&A
expense is estimated to be $0.88 per BOE (previous forecast was $0.97 per BOE)
and interest expense is forecasted at $0.98 per BOE (previous forecast was
$0.93 per BOE).
2018 Guidance
WTI crude oil prices are forecasted to average US$52.00 per barrel in 2018, up
4% from the estimated average price of US$50.00 per barrel in 2017. AECO
natural gas prices are forecasted to average $2.15 per GJ in 2017, unchanged
from the estimated average price in 2017. Kelt is expected to realize a
premium (prior to adjusting for heat content) of approximately 30% to the
average forecasted AECO price in 2018 as a result of its diversified gas
market contracts.
The Company’s Board of Directors has approved an initial capital expenditure
budget of $210.0 million for 2018. Kelt expects to drill 21 gross (19.5 net)
wells in 2018, however the Company expects to complete 29 gross (27.5 net)
wells in 2018 as there are expected to be 8 gross (8.0 net) drilled but
un-completed (“DUC”) wells from 2017.
Forecasted average production in 2018 is estimated to be from 28,500 BOE per
day to 29,500 BOE per day, representing a 31% to 35% increase from forecasted
average production of 21,800 BOE per day in 2017. It is estimated that this
2018 forecasted average production will be weighted 47% to oil/NGLs and 53% to
gas. However, based on the Company’s forecasted commodity prices for 2018, 83%
of forecasted operating income in 2018 is expected to be generated from oil
and NGLs versus 17% from gas.
After giving effect to the aforementioned production estimates, commodity
price assumptions and estimated expenses, funds from operations for 2018 is
forecasted to be approximately $175.0 million or $0.97 per common share,
diluted. Kelt estimates that the Company’s bank debt, net of working capital,
will be approximately $155.0 million as at December 31, 2018 (0.9 times
forecasted 2018 funds from operations). Royalties are expected to average
10.5% of revenue in 2018. On average during 2018, combined production and
transportation expense is estimated to be $12.91 per BOE ($9.49 per BOE and
$3.42 per BOE respectively), G&A expense is estimated to be $0.76 per BOE and
interest expense is forecasted at $0.85 per BOE.
The table below outlines the Company’s forecasted financial and operating
results for 2017 and new guidance for 2018:
/T/
—————————————————————————-
(CA$ millions, except as
otherwise indicated) 2018 Budget 2017 Forecast Change
—————————————————————————-
Average Production
Oil (bbls/d) 10,600 – 11,000 6,830 55% – 61%
NGLs (bbls/d) 2,800 – 2,900 2,370 18% – 22%
Gas (mmcf/d) 90.6 – 93.6 75.6 20% – 24%
—————————————————————————-
Combined (BOE/d) 28,500 – 29,500 21,800 31% – 35%
—————————————————————————-
Production per million common
shares (BOE/d) (1) 159 – 165 124 28% – 33%
—————————————————————————-
Forecasted Average Commodity
Prices
WTI oil price (US$/bbl) 52.00 50.00 4%
Canadian Light Sweet ($/bbl) 61.52 60.81 1%
NYMEX natural gas price
(US$/MMBTU) 3.15 3.15 0%
AECO natural gas price ($/GJ) 2.15 2.15 0%
Average Exchange Rate (US$/CA$) 0.794 0.774 3%
Capital Expenditures
Drilling & completions 135.0 144.0 – 6%
Facilities, pipeline & well
equipment 65.0 67.0 – 3%
Land, seismic & property
acquisitions 10.0 15.0 – 33%
Property dispositions – (111.0) – 100%
—————————————————————————-
Net Capital Expenditures 210.0 115.0 83%
—————————————————————————-
Funds from operations (1) 175.0 110.0 59%
Per common share, diluted 0.97 0.62 56%
Bank debt, net of working
capital, at year-end (1)(2) 155.0 120.0 29%
Net bank debt to trailing annual
funds from operations ratio (1) 0.9 x 1.1 x – 18%
Weighted average common shares
outstanding (millions) 179.0 176.5 1%
Common shares issued and
outstanding (millions) 179.1 178.9 0%
—————————————————————————-
/T/
(1) Refer to advisories regarding non-GAAP financial measures and other key
performance indicators.
(2) In addition to bank debt, the Company has $90.0 million principal amount
of convertible debentures outstanding with a coupon of 5% per annum, maturing
May 31, 2021.
Changes in forecasted commodity prices and variances in production estimates
can have a significant impact on estimated funds from operations and profit.
Please refer to the advisories regarding forward-looking statements and to the
cautionary statement below.
The information set out herein is “financial outlook” within the meaning of
applicable securities laws. The purpose of this financial outlook is to
provide readers with disclosure regarding Kelt’s reasonable expectations as to
the anticipated results of its proposed business activities for the balance of
2017 and for the calendar year 2018. Readers are cautioned that this financial
outlook may not be appropriate for other purposes.
Advisory Regarding Forward-Looking Statements
This press release contains forward-looking statements and forward-looking
information within the meaning of applicable securities laws. The use of any
of the words “expect”, “anticipate”, “continue”, “estimate”, “objective”,
“ongoing”, “may”, “will”, “project”, “should”, “believe”, “plans”, “intends”,
“potentially” and similar expressions are intended to identify forward-looking
information or statements. In particular, this press release contains
forward-looking statements pertaining to the following: Kelt’s intention to
incur sufficient qualifying expenditures to fully satisfy the Company’s
commitments in respect of the Private Placements of flow-through shares; the
objective to take advantage of favourable service costs during the fourth
quarter of 2017 and the possibility that service costs to drill and complete
wells may increase in the first quarter of 2018; the Company’s ability to
continue accumulating land at a low-cost in its core operating areas; positive
indicators in the current economic environment that the Company believes may
lead to higher oil and gas prices in 2018; and the Company’s expected future
financial position and operating results, as well as the amount and timing of
future development capital expenditures. Statements relating to “reserves” or
“resources” are 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. Actual reserves may be
greater than or less than the estimates provided herein.
Although Kelt believes that the expectations and assumptions on which the
forward-looking statements are based are reasonable, undue reliance should not
be placed on the forward-looking statements because Kelt cannot give any
assurance that they will prove to be correct. Since forward-looking statements
address future events and conditions, by their very nature they involve
inherent risks and uncertainties. Actual results could differ materially from
those currently anticipated due to a number of factors and risks. These
include, but are not limited to, the risks associated with the oil and gas
industry in general (e.g., operational risks in development, exploration and
production; delays or changes in plans with respect to exploration or
development projects or capital expenditures; the uncertainty of reserve
estimates; the uncertainty of estimates and projections relating to
production, costs and expenses; failure to obtain necessary regulatory
approvals for planned operations; health, safety and environmental risks;
uncertainties resulting from potential delays or changes in plans with respect
to exploration or development projects or capital expenditures; volatility of
commodity prices, currency exchange rate fluctuations; imprecision of reserve
estimates; and competition from other explorers) as well as general economic
conditions, stock market volatility; and the ability to access sufficient
capital. We caution that the foregoing list of risks and uncertainties is not
exhaustive.
In addition, the reader is cautioned that historical results are not
necessarily indicative of future performance. The forward-looking statements
contained herein are made as of the date hereof and the Company does not
intend, and does not assume any obligation, to update or revise any
forward-looking statements, whether as a result of new information, future
events or otherwise unless expressly required by applicable securities laws.
Non-GAAP Financial Measures and Other Key Performance Indicators
This press release contains certain financial measures, as described below,
which do not have standardized meanings prescribed by GAAP. In addition, this
press release contains other key performance indicators (“KPI”), financial and
non-financial, that do not have standardized meanings under the applicable
securities legislation. As these non-GAAP financial measures and KPI are
commonly used in the oil and gas industry, the Company believes that their
inclusion is useful to investors. The reader is cautioned that these amounts
may not be directly comparable to measures for other companies where similar
terminology is used.
Non-GAAP financial measures
“Operating income” is calculated by deducting royalties, production expenses
and transportation expenses from petroleum and natural gas revenue, after
realized gains or losses on associated financial instruments. The Company
refers to operating income expressed per unit of production as an “Operating
netback”. “Funds from operations” is calculated as cash provided by operating
activities before changes in non-cash operating working capital. “Adjusted
funds from operations” is calculated by adding back to funds from operations
(if applicable): transaction costs associated with acquisitions and
dispositions, provisions for potential credit losses, and settlement of
decommissioning obligations. Adjusted funds from operations per common share
is calculated on a consistent basis with profit (loss) per common share, using
basic and diluted weighted average common shares as determined in accordance
with GAAP. Adjusted funds from operations and operating income or netbacks are
used by Kelt as key measures of performance and are not intended to represent
operating profits nor should they be viewed as an alternative to cash provided
by operating activities, profit or other measures of financial performance
calculated in accordance with GAAP.
Throughout this press release, the term “net bank debt” is used synonymously
with, and is equal to, “bank debt, net of working capital”. “Net bank debt” is
calculated by adding the working capital deficiency to bank debt. The working
capital deficiency is equal to total current assets net of total current
liabilities. The Company uses a “net bank debt to trailing funds from
operations ratio” as a benchmark on which management monitors the Company’s
capital structure and short-term financing requirements. Management believes
that this ratio, which is a non-GAAP financial measure, provides investors
with information to understand the Company’s liquidity risk. The “net bank
debt to trailing funds from operations ratio” is also indicative of the “debt
to cash flow” calculation used to determine the applicable margin for a
quarter under the Company’s Credit Facility agreement (though the calculation
may not always be a precise match, it is representative).
Other KPI
“Production per common share” is calculated by dividing total production by
the basic weighted average number of common shares outstanding, as determined
in accordance with GAAP.
Measurements
All dollar amounts are referenced in thousands of Canadian dollars, except
when noted otherwise. This press release contains various references to the
abbreviation BOE which means barrels of oil equivalent. Where amounts are
expressed on a BOE basis, natural gas volumes have been converted to oil
equivalence at six thousand cubic feet per barrel and sulphur volumes have
been converted to oil equivalence at 0.6 long tons per barrel. The term BOE
may be misleading, particularly if used in isolation. A BOE conversion ratio
of six thousand cubic feet per barrel is based on an energy equivalency
conversion method primarily applicable at the burner tip and does not
represent a value equivalency at the wellhead and is significantly different
than the value ratio based on the current price of crude oil and natural gas.
This conversion factor is an industry accepted norm and is not based on either
energy content or current prices. Such abbreviation may be misleading,
particularly if used in isolation. References to “oil” in this press release
include crude oil and field condensate. References to “natural gas liquids” or
“NGLs” include pentane, butane, propane, and ethane. References to “liquids”
include field condensate and NGLs. References to “gas” in this discussion
include natural gas and sulphur.
Abbreviations
/T/
bbls barrels
bbls/d barrels per day
mcf thousand cubic feet
mcf/d thousand cubic feet per day
mmcf million cubic feet
mmcf/d million cubic feet per day
tcf trillion cubic feet
MMBTU million British Thermal Units
GJ gigajoule
BOE barrel of oil equivalent
BOE/d barrel of oil equivalent per day
NGLs natural gas liquids
LNG liquefied natural gas
AECO Alberta Energy Company “C” Meter Station of the NOVA Pipeline
System
NIT NOVA Inventory Transfer (“AB-NIT”), being the reference price at
the AECO Hub
WTI West Texas Intermediate
NYMEX New York Mercantile Exchange
Station 2 Spectra Energy receipt location
US$ United States dollars
CA$ Canadian dollars
TSX the Toronto Stock Exchange
KEL trading symbol for Kelt Exploration Ltd. common shares on the
TSX
KEL.DB trading symbol for Kelt Exploration Ltd. 5% convertible
debentures on the TSX
CDE Canadian Development Expenses, as defined by the Income Tax Act
(Canada)
CEE Canadian Exploration Expenses, as defined by the Income Tax Act
(Canada)
GAAP Generally Accepted Accounting Principles
KPI Key Performance Indicators
/T/
– END RELEASE – 09/11/2017
For further information:
For further information, please contact:
Kelt Exploration Ltd.
Suite 300, 311 – 6th Avenue SW
Calgary, Alberta, Canada T2P 3H2
David J. Wilson
President and Chief Executive Officer
(403) 201-5340
Sadiq H. Lalani
Vice President and Chief Financial Officer
(403) 215-5310
Or visit our website at www.keltexploration.com
COMPANY:
FOR: KELT EXPLORATION LTD.
TSX Symbol: KEL
INDUSTRY: Energy and Utilities – Oil and Gas
RELEASE ID: 20171109CC001
Press Release from Marketwired 1-866-736-3779
All press releases are written by the client and have NO affiliation with the news copy written by The Canadian Press. Any questions that arise due to the content or information provided in the press release should be directed to the company/organization
issuing the release, not to The Canadian Press.
Canadians Should Decide What to do With Their Money – Not Politicians and Bureaucrats