2023 YEAR-END
RESERVES
CALGARY, ALBERTA (March 1, 2024) -
Touchstone Exploration Inc. ("Touchstone",
"we", "our" or the "Company") (TSX, LSE:
TXP) announces 2023 year-end reserves.
Touchstone's independent reserves evaluation was prepared by GLJ Ltd.
("GLJ") with an
effective date of December 31, 2023 (the "Reserves Report"). Highlights of our total proved
developed producing ("PDP"), total proved ("1P"), total proved plus
probable ("2P") and total proved plus probable plus possible ("3P")
reserves from the Reserves Report are provided below. Unless
otherwise stated, all financial amounts referenced
herein are stated in United States dollars.
Financial information contained herein is based on
the Company's unaudited results for the year ended December 31,
2023 and is subject to change. Readers are further cautioned to
read the applicable advisories contained herein.
Touchstone's 2023 year-end reserves
reflect the initial transition of our Cascadura production base
into the PDP reserves category as we brought onstream the first two
Cascadura wells, Cascadura-1ST1 and Cascadura Deep-1. In addition
to successfully constructing and commissioning the Cascadura
natural gas and liquids facility in 2023, we also prepared for our
Cascadura C delineation and development program.
In 2023 we achieved initial
production from our Cascadura field which produced net volumes of
37.4 MMcf/d of natural gas and 622 bbls/d of natural gas liquids in
the fourth quarter of 2023, contributing to corporate average
quarterly net production volumes of 8,504 boe/d and average 2023
annual net production volumes of 3,981 boe/d.
2023 Year-end Reserves Report Highlights
· Relative to year-end 2022 and after 2023 production, we
increased gross PDP reserves by 180 percent to 13,547 Mboe,
decreased gross 1P reserves by 12 percent to 33,696 Mboe, decreased
gross 2P reserves by 10 percent to 67,379 Mboe and decreased gross
3P reserves by 10 percent to 108,859 Mboe in 2023.
· PDP
reserves replaced 2023 annual production by 699 percent, reflecting
Cascadura-1ST1 and Cascadura Deep-1 natural gas and associated
liquids volumes that were brought online in 2023.
· With
the addition of Cascadura property reserves, PDP reserves represent
40 percent of 1P reserves, reflecting an attractive ratio of base
production to low risk proved undeveloped ("PUD") drilling
targets.
· Reductions in our 1P, 2P, and 3P year-end reserves balances
from 2022 reflected the removal of eight PUD locations on our
non-core legacy crude oil blocks and Royston, technical revisions
to the natural gas liquids yields at Cascadura, increased annual
production volumes in 2023 and a limited 2023 development capital
program.
· Our net
present value of future net revenues discounted at 10 percent
("NPV10") on a before tax PDP basis increased by 142 percent to
$151.4 million, decreased by 30 percent to $372.5 million on a 1P
basis, decreased by 27 percent to $730.1 million on a 2P basis, and
decreased by 29 percent to $1.05 billion on a 3P basis from the
prior year.
· Realized after tax PDP NPV10 of $99.8 million representing an
increase of 93 percent from the prior year, after tax 1P NPV10
decreased by 25 percent from year-end 2022 to $191.4 million, after
tax 2P NPV10 decreased by 24 percent from the prior year to $342.5
million and after tax 3P NPV10 decreased by 26 percent from 2022 to
$482.6 million.
· We
continue to maintain a long producing reserve life index of 7.9
years 1P and 14.4 years 2P, reflecting the low decline nature of
our asset base.
· The
Cascadura-2 well was drilled subsequent to the effective date of
the Reserves Report and will be reflected in our future reserve
evaluations.
2023 Year-end Reserves Report Summary
Touchstone's year-end light and
medium crude oil, heavy crude oil, conventional natural gas and
natural gas liquid reserves in Trinidad were evaluated by
independent reserves evaluator, GLJ, in accordance with
definitions, standards and procedures contained in the Canadian Oil
and Gas Evaluation Handbook ("COGE Handbook") and National
Instrument 51-101 - Standards of
Disclosure for Oil and Gas Activities ("NI 51-101").
Additional reserves information as required under NI 51-101 will be
included in the Company's Annual Information Form, which will be
filed on SEDAR+ (www.sedarplus.ca) on or before March 30, 2024.
The reserve estimates set forth
below are based upon GLJ's Reserves Report dated February 29, 2024
with an effective date of December 31, 2023. The Reserves Report
uses the average price forecasts of the three leading Canadian oil
and gas evaluation consultants (GLJ, McDaniel & Associates
Consultants Ltd. and Sproule Associates Ltd. (collectively, the
"Consultants")). All values in this
announcement are based on the three Consultants' average forecast
pricing and GLJ's estimates of future operating and capital costs
as of December 31, 2023. Please refer to "Advisories: Reserves Disclosure" for
further information. In certain tables set forth below, the columns
may not add due to rounding.
2023 Reserves Summary by
Category
|
PDP
|
1P
|
2P
|
3P
|
|
|
|
|
|
Total gross
reserves(1) (Mboe)
|
13,547
|
33,696
|
67,379
|
108,859
|
Reserve additions
(reductions)(2) (Mboe)
|
10,158
|
(3,313)
|
(6,241)
|
(10,281)
|
NPV10 before income
tax(3) ($000's)
|
151,433
|
372,547
|
730,065
|
1,052,803
|
NPV10 after income
tax(3) ($000's)
|
99,791
|
191,466
|
342,527
|
482,575
|
|
|
|
|
|
Notes:
(1) Gross reserves
are the Company's working interest share before deduction of
royalties.
(2)
Reserve additions (reductions) exclude 2023 annual
production. See "Advisories: Oil
and Gas Metrics".
(3) Based on the
Consultants' average December 31, 2023 forecast prices and costs.
See "Forecast prices and
costs" herein.
Year-Over-Year Reserves
Data
|
December 31,
2023
|
December 31,
2022(1)
|
% Change
|
|
|
|
|
PDP gross
reserves(2) (Mboe)
|
13,547
|
4,843
|
180
|
1P gross
reserves(2) (Mboe)
|
33,696
|
38,463
|
(12)
|
2P gross reserves(2)
(Mboe)
|
67,379
|
75,074
|
(10)
|
3P gross
reserves(2) (Mboe)
|
108,859
|
120,594
|
(10)
|
|
|
|
|
PDP NPV10 before income
tax(3) ($000's)
|
151,433
|
62,561
|
142
|
1P NPV10 before income
tax(3) ($000's)
|
372,547
|
530,264
|
(30)
|
2P NPV10 before income
tax(3) ($000's)
|
730,065
|
993,714
|
(27)
|
3P NPV10 before income
tax(3) ($000's)
|
1,052,803
|
1,473,380
|
(29)
|
|
|
|
|
PDP NPV10 after income
tax(3) ($000's)
|
99,791
|
51,770
|
93
|
1P NPV10 after income
tax(3) ($000's)
|
191,446
|
256,623
|
(25)
|
2P NPV10 after income
tax(3) ($000's)
|
342,527
|
450,624
|
(24)
|
3P NPV10 after income
tax(3) ($000's)
|
482,575
|
654,913
|
(26)
|
|
|
|
|
Notes:
(1) Prior year
reserve estimates per GLJ's independent reserves evaluation dated
March 3, 2023 with an effective date of December 31,
2022.
(2) Gross reserves
are the Company's working interest share before deduction of
royalties.
(3) Based on the
three Consultants' average December 31, 2023 forecast prices and
costs. See "Forecast prices and
costs" herein.
Summary of Crude Oil and
Natural Gas Reserves by Product Type
Company Gross(1) Reserves
|
Light and Medium Crude Oil
(Mbbl)
|
Heavy Crude
Oil
(Mbbl)
|
Conventional
Natural Gas
(MMcf)
|
Natural Gas Liquids
(Mbbl)(2)
|
Total Oil Equivalent
(Mboe)
|
|
|
|
|
|
|
Proved
|
|
|
|
|
|
Developed producing
|
3,360
|
224
|
56,296
|
580
|
13,547
|
Developed non-producing
|
1,331
|
10
|
4,020
|
37
|
2,048
|
Undeveloped
|
3,846
|
0
|
80,427
|
849
|
18,100
|
Total 1P
|
8,538
|
234
|
140,743
|
1,467
|
33,696
|
|
|
|
|
|
|
Probable
|
8,084
|
58
|
145,180
|
1,344
|
33,683
|
Total 2P
|
16,622
|
292
|
285,923
|
2,811
|
67,379
|
|
|
|
|
|
|
Possible
|
5,141
|
87
|
205,911
|
1,933
|
41,480
|
Total 3P
|
21,763
|
379
|
491,834
|
4,744
|
108,859
|
Company Net(3) Reserves
|
Light and Medium Crude Oil
(Mbbl)
|
Heavy Crude
Oil
(Mbbl)
|
Conventional
Natural Gas
(MMcf)
|
Natural Gas Liquids
(Mbbl)(2)
|
Total Oil Equivalent
(Mboe)
|
|
|
|
|
|
|
Proved
|
|
|
|
|
|
Developed producing
|
2,022
|
199
|
49,259
|
508
|
10,939
|
Developed non-producing
|
856
|
9
|
3,518
|
32
|
1,484
|
Undeveloped
|
2,786
|
0
|
70,374
|
743
|
15,258
|
Total 1P
|
5,664
|
209
|
123,150
|
1,283
|
27,681
|
|
|
|
|
|
|
Probable
|
6,056
|
51
|
127,032
|
1,176
|
28,456
|
Total 2P
|
11,720
|
260
|
250,183
|
2,460
|
56,137
|
|
|
|
|
|
|
Possible
|
3,780
|
78
|
180,171
|
1,691
|
35,578
|
Total 3P
|
15,500
|
338
|
430,354
|
4,151
|
91,715
|
Notes:
(1) Gross reserves
are the Company's working interest share before deduction of
royalties.
(2) NGLs are
comprised of 100% condensate.
(3) Net reserves
are the Company's working interest share after the deduction of
royalty obligations.
Summary of Net Present Values
of Future Net Revenues
Net
Present Values Before Income Taxes(1) ($000's)
|
Undiscounted
|
Discounted at
5%
|
Discounted at
10%
|
Discounted at
15%
|
Discounted at
20%
|
|
|
|
|
|
|
Proved
|
|
|
|
|
|
Developed producing
|
203,893
|
173,513
|
151,433
|
134,704
|
121,630
|
Developed non-producing
|
41,188
|
32,603
|
27,853
|
24,538
|
21,988
|
Undeveloped
|
316,080
|
243,189
|
193,262
|
157,745
|
131,632
|
Total 1P
|
561,162
|
449,304
|
372,547
|
316,987
|
275,251
|
|
|
|
|
|
|
Probable
|
708,321
|
487,694
|
357,518
|
274,398
|
218,055
|
Total 2P
|
1,269,483
|
936,998
|
730,065
|
591,386
|
493,306
|
|
|
|
|
|
|
Possible
|
920,790
|
504,989
|
322,738
|
228,824
|
173,899
|
Total 3P
|
2,190,273
|
1,441,987
|
1,052,803
|
820,210
|
667,205
|
Note:
(1) Based on the
three Consultants' average December 31, 2023 forecast prices and
costs. See "Forecast prices and
costs" herein.
Net
Present Values After Income Taxes(1)(2) ($000's)
|
Undiscounted
|
Discounted at
5%
|
Discounted at
10%
|
Discounted at
15%
|
Discounted at
20%
|
|
|
|
|
|
|
Proved
|
|
|
|
|
|
Developed producing
|
118,430
|
109,202
|
99,791
|
91,684
|
84,890
|
Developed non-producing
|
14,408
|
13,126
|
11,716
|
10,546
|
9,583
|
Undeveloped
|
137,087
|
103,315
|
79,938
|
63,308
|
51,161
|
Total 1P
|
269,925
|
225,643
|
191,446
|
165,539
|
145,633
|
|
|
|
|
|
|
Probable
|
296,550
|
207,139
|
151,082
|
114,601
|
89,695
|
Total 2P
|
566,475
|
432,782
|
342,527
|
280,140
|
235,328
|
|
|
|
|
|
|
Possible
|
386,142
|
216,473
|
140,048
|
100,088
|
76,482
|
Total 3P
|
952,617
|
649,255
|
482,575
|
380,228
|
311,810
|
Notes:
(1) Based on the
three Consultants' average December 31, 2023 forecast prices and
costs. See "Forecast prices and
costs" herein.
(2) The after-tax
net present values prepared by GLJ in the evaluation of the
Company's petroleum and natural gas assets presented herein are
calculated by considering current Trinidad tax regulations and are
based on the Company's estimated tax pools and non-capital losses
as of December 31, 2023. The values reflect the expected income tax
burden on the assets on a consolidated basis. Values do not
represent an estimate of the value at the business entity level or
consider tax planning, which may be significantly different. See
"Advisories: Unaudited Financial
Information".
Reconciliation of Gross
Reserves by Product Type
The following table sets forth a
reconciliation of the Company's total gross proved, gross probable
and gross proved plus probable reserves as of December 31, 2023 by
product type against such reserves as at December 31, 2022 based on
forecast prices and cost assumptions.
Reserves Category and Factors
|
Light and Medium Crude Oil
(Mbbl)
|
Heavy Crude
Oil
(Mbbl)
|
Conventional
Natural Gas
(MMcf)
|
Natural Gas Liquids
(Mbbl)(1)
|
Total Oil Equivalent
(Mboe)
|
|
|
|
|
|
|
Total Proved
|
|
|
|
|
|
December 31,
2022(2)
|
9,977
|
468
|
146,677
|
3,571
|
38,463
|
Extensions and improved
recovery(3)
|
327
|
-
|
-
|
-
|
327
|
Technical
revisions(4)
|
(1,359)
|
(209)
|
(242)
|
(2,030)
|
(3,638)
|
Economic
factors(5)
|
(2)
|
-
|
-
|
-
|
(2)
|
Production
|
(406)
|
(25)
|
(5,692)
|
(74)
|
(1,454)
|
December 31, 2023
|
8,538
|
234
|
140,743
|
1,467
|
33,696
|
|
|
|
|
|
|
Total Probable
|
|
|
|
|
|
December 31,
2022(2)
|
8,711
|
416
|
144,850
|
3,342
|
36,611
|
Extensions and improved
recovery(3)
|
82
|
-
|
-
|
-
|
82
|
Technical
revisions(4)
|
(702)
|
(359)
|
330
|
(1,998)
|
(3,003)
|
Economic
factors(5)
|
(7)
|
-
|
-
|
-
|
(7)
|
Production
|
-
|
-
|
-
|
-
|
-
|
December 31, 2023
|
8,084
|
58
|
145,180
|
1,344
|
33,683
|
|
|
|
|
|
|
Total Proved plus Probable
|
|
|
|
|
|
December 31,
2022(2)
|
18,688
|
884
|
291,527
|
6,913
|
75,074
|
Extensions and improved
recovery(3)
|
409
|
-
|
-
|
-
|
409
|
Technical
revisions(4)
|
(2,061)
|
(567)
|
87
|
(4,028)
|
(6,641)
|
Economic
factors(5)
|
(9)
|
-
|
-
|
-
|
(9)
|
Production
|
(406)
|
(25)
|
(5,692)
|
(74)
|
(1,454)
|
December 31, 2023
|
16,622
|
292
|
285,923
|
2,811
|
67,379
|
Notes:
(1) NGLs are
comprised of 100 percent condensate.
(2) Prior year
reserve estimates per GLJ's independent reserves evaluation dated
March 3, 2023 with an effective date of December 31,
2022.
(3) Reserve
amounts for Infill Drilling, Extensions and Improved Recovery are
combined and reported as "Extensions and Improved
Recovery".
(4) Technical
revisions factor includes all changes in reserves due to well
performance and previously booked wells which were drilled in the
year.
(5)
Economic factors are the change in reserves
exclusively due to changes in pricing.
December 31, 2023 gross proved plus
probable reserves were 67,379 Mboe, representing a 7,695 Mboe or 10
percent decrease from the 75,074 Mboe reported in the prior year.
Relative to December 31, 2022, light and medium crude oil reserves
decreased by 2,006 Mbbl. The annual decline predominately reflected
a combination of annual production, the removal of two proved
undeveloped drilling locations at Royston and six proved
undeveloped drilling locations at our CO-2 field, partially offset
by two new proved undeveloped drilling locations at our CO-1
property and improved recovery from well recompletions at our WD-4
field. Proved plus probable heavy crude oil reserves decreased by
592 Mbbl from the prior year, reflecting the removal of all future
recompletion activity at our Fyzabad property and 2023 production.
Proved plus probable conventional natural gas reserves decreased by
5,604 MMcf relative to December 31, 2022, mainly attributed to
annual Cascadura and Coho field production. Proved plus probable
natural gas liquids reserves decreased by 4,102 Mbbl in comparison
to December 31, 2022, reflecting a reduction in forecasted
Cascadura natural gas liquids yields and 2023 annual
production.
Future Development
Costs
The following table provides
information regarding the development costs deducted in the
estimation of the Company's future net revenue using forecast
prices and costs as included in the Reserves Report.
Year ($000's)
|
PDP
|
1P
|
2P
|
3P
|
|
|
|
|
|
2024
|
50
|
19,270
|
28,260
|
28,260
|
2025
|
-
|
12,143
|
24,786
|
24,786
|
2026
|
-
|
21,505
|
28,236
|
28,236
|
2027
|
-
|
11,493
|
40,857
|
40,857
|
2028
|
-
|
12,995
|
18,537
|
18,537
|
Thereafter
|
-
|
-
|
-
|
-
|
Total undiscounted
|
50
|
77,406
|
140,676
|
140,676
|
Total discounted at 10% per year
|
48
|
62,540
|
112,018
|
112,018
|
The following table sets forth the
changes in undiscounted future development costs ("FDC") included
in the Reserves Report against such costs in our December 31, 2022
reserves report prepared by GLJ dated March 3, 2023.
($000's unless otherwise stated)
|
PDP
|
1P
|
2P
|
3P
|
|
|
|
|
|
(Decrease) increase in forecasted
well costs
|
(140)
|
11,692
|
19,414
|
19,414
|
Decrease in forecasted well
locations
|
-
|
(15,630)
|
(15,481)
|
(15,481)
|
Decrease in forecasted facility and
pipeline costs
|
-
|
(5,400)
|
(4,623)
|
(4,623)
|
Total decrease in FDC from 2022
|
(140)
|
(9,338)
|
(690)
|
(690)
|
Total decrease in FDC from 2022 (%)
|
(74)
|
(11)
|
-
|
-
|
Forecast Pricing and
Costs
Forecast pricing and costs are
prices and costs that are generally acceptable, in the opinion of
GLJ, as being a reasonable outlook of the future as of the
evaluation effective date. The forecast cost assumptions consider
inflation with respect to future operating and capital costs. The
following table sets forth the benchmark reference commodity prices
and inflation rates reflected in the Reserves Data as of December
31, 2023. These price assumptions were provided to the Company by
GLJ and represented the average price
forecast of the three Consultants as of the date
of the Reserves Report.
Consultants Average Price
Forecast
|
Forecast Year
|
Brent Spot Crude
Oil(1)
($/bbl)
|
Henry Hub Natural
Gas(1)
($/MMBtu)
|
Inflation
Rate
(% per
year)
|
|
|
|
|
2024
|
78.00
|
2.75
|
0.0
|
2025
|
79.18
|
3.64
|
2.0
|
2026
|
80.36
|
4.02
|
2.0
|
2027
|
81.79
|
4.10
|
2.0
|
|
|
|
|
2028
|
83.41
|
4.18
|
2.0
|
2029
|
85.09
|
4.27
|
2.0
|
2030
|
86.79
|
4.35
|
2.0
|
2031
|
88.52
|
4.44
|
2.0
|
2032
|
90.29
|
4.53
|
2.0
|
2033
|
92.10
|
4.62
|
2.0
|
Thereafter
|
+2.0% /
year
|
+2.0% /
year
|
2.0
|
|
|
|
|
Note:
(1) This summary
table identifies benchmark reference pricing schedules that might
apply to a reporting issuer. Product sales prices will reflect
these reference prices with further adjustments for specific
marketing arrangements, quality differentials and transportation to
point of sale.
Capital Program
Efficiency
|
2023
|
2023 - 2019
Total
|
1P
|
2P
|
1P
|
2P
|
|
|
|
|
|
Estimated capital
expenditures(1)(2) ($000's)
|
18,949
|
18,949
|
88,213
|
88,213
|
Change in FDC ($000's)
|
(9,338)
|
(690)
|
31,407
|
72,034
|
Finding and development ("F&D")
costs(2)(3)
($000's)
|
9,611
|
18,259
|
119,620
|
160,247
|
|
|
|
|
|
Reserve (reductions) additions(3)(4) (Mboe)
|
(3,313)
|
(6,241)
|
26,161
|
51,791
|
|
|
|
|
|
F&D costs per boe(2)(3) ($/boe)
|
n/a
|
n/a
|
4.57
|
3.09
|
|
|
|
|
|
Estimated operating netback(1)(2) ($/boe)
|
18.04
|
18.04
|
22.62
|
22.62
|
|
|
|
|
|
Recycle ratio(2)(3)
|
n/a
|
n/a
|
4.9x
|
7.3x
|
Notes:
(1) Financial
information is based on the Company's preliminary 2023 unaudited
financial statements and is therefore subject to change. See
"Advisories: Unaudited Financial
Information".
(2)
Non-GAAP financial measure. See "Advisories: Non-GAAP Financial
Measures".
(3)
See "Advisories:
Reserves Disclosure" and "Advisories: Oil and Gas
Metrics".
(4)
Based on gross reserves, which are the Company's
working interest share before deduction of royalties.
January 2024 Sales Volumes and Realized
Prices
In January 2024, we achieved average net sales
volumes of 7,436 boe/d as follows:
· Cascadura contributed net sales volumes of 5,799 boe/d
consisting of:
- net
natural gas sales volumes of 32.8 MMcf/d or 5,460 boe/d with a
realized price of $2.47 per Mcf; and
- net
natural gas liquids volumes of 339 bbls/d with an average realized
price of $68.15 per barrel;
· Coho
field net average natural gas sales volumes were 2.8 MMcf/d or 467
boe/d at a realized price of $2.28 per Mcf (excluding third party
processing fees); and
· average
net daily crude oil sales volumes were 1,170 bbls/d per day with an
average realized price of $68.15 per barrel.
January 2024 production decreased by
approximately 11 percent from December 2023, attributed to natural
declines and the Cascadura Deep-1 well being shut in for four days
in the month.
Touchstone Exploration Inc.
Touchstone Exploration Inc. is a
Calgary, Alberta based company engaged in the business of acquiring
interests in petroleum and natural gas rights and the exploration,
development, production and sale of petroleum and natural gas.
Touchstone is currently active in onshore properties located in the
Republic of Trinidad and Tobago. The Company's common shares are
traded on the Toronto Stock Exchange and the AIM market of the
London Stock Exchange under the symbol "TXP". For further
information about Touchstone, please visit our website at
www.touchstoneexploration.com
or contact:
Touchstone Exploration Inc.
Paul Baay, President and Chief
Executive Officer
James Shipka, Chief Operating
Officer
Brian Hollingshead, VP Engineering
and Business Development
|
Tel: +1 (403) 750-4487
|
Shore Capital (Nominated Advisor and Joint
Broker)
Daniel Bush / Toby Gibbs / Iain
Sexton
|
Tel: +44 (0) 207 408 4090
|
Canaccord Genuity (Joint Broker)
Adam James / Ana
Ercegovic
|
Tel: +44 (0) 207 523 8000
|
FTI
Consulting (Financial PR)
Nick Hennis / Ben
Brewerton
|
Tel: +44 (0) 203 727 1000
Email: touchstone@fticonsulting.com
|
Advisories
Forward-Looking
Statements
The information provided in this
announcement contains certain forward-looking statements and
information (collectively, "forward-looking statements") within the
meaning of applicable securities laws. Such forward-looking
statements include, without limitation, forecasts, estimates,
expectations and objectives for future operations that are subject
to assumptions, risks and uncertainties, many of which are beyond
the control of the Company. Forward-looking statements are
statements that are not historical facts and are generally, but not
always, identified by the words "expect", "plan", "anticipate",
"believe", "intend", "maintain", "continue to", "pursue", "design",
"result in", "sustain" "estimate", "potential", "growth",
"near-term", "long-term", "forecast", "contingent" and similar
expressions, or are events or conditions that "will", "would",
"may", "could" or "should" occur or be achieved. The
forward-looking statements contained in this announcement speak
only as of the date hereof and are expressly qualified by this
cautionary statement.
Specifically, this announcement
includes, but is not limited to, forward-looking statements
relating to: the Company's business plans, strategies, priorities
and development plans; the sustainability and low decline nature of
our asset base; estimated crude oil, NGL and natural gas reserves
and the net present values of future net revenue therefrom; and the
forecasted future production, commodity prices, inflation rates and
all future costs used by GLJ in their evaluation. The Company's
actual decisions, activities, results, performance, or achievement
could differ materially from those expressed in, or implied by,
such forward-looking statements and accordingly, no assurances can
be given that any of the events anticipated by the forward-looking
statements will transpire or occur or, if any of them do, what
benefits that Touchstone will derive from them.
Information and statements relating
to reserves are by their nature 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 can be profitably produced in the
future. The recovery and reserve estimates of Touchstone's reserves
provided herein are estimates only, and there is no guarantee that
the estimated reserves will be recovered. Consequently, actual
results may differ materially from those anticipated in the
forward-looking statements (see "Advisories: Reserves
Disclosure").
Although the Company 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 the Company can
give no 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. Certain of these
risks are set out in more detail in the Company's 2022 Annual
Information Form dated March 23, 2023 which is available under the
Company's profile on SEDAR+ (www.sedarplus.ca) and on the Company's website (www.touchstoneexploration.com).
The forward-looking statements contained in this announcement are
made as of the date hereof, and except as may be required by
applicable securities laws, the Company assumes no obligation or
intent to update publicly or revise any forward-looking statements
made herein or otherwise, whether as a result of new information,
future events or otherwise.
This announcement contains inside
information for the purposes of Article 7 of the UK version of the
Market Abuse Regulation (EU) No.596/2014, which forms part of UK
law by virtue of the European Union (Withdrawal) Act
2018.
Reserves
Disclosure
The disclosure in this announcement
summarizes certain information contained in the Reserves Report but
represents only a portion of the disclosure required under NI
51-101. Full disclosure with respect to the Company's reserves as
at December 31, 2023 will be contained in the Company's Annual
Information Form for the year ended December 31, 2023 which will be
filed on SEDAR+ (www.sedarplus.ca) on or before March 30, 2024. All
reserves values, future net revenue and ancillary information
contained in this announcement are derived from the Reserves Report
unless otherwise noted. Unless otherwise noted, reserve references
in this announcement are Company "gross reserves". Company gross
reserves are the Company's total working interest reserves before
the deduction of any royalties payable by the Company. Estimates of
reserves and future net revenue for individual properties may not
reflect the same level of confidence as estimates of reserves and
future net revenue for all properties, due to the effect of
aggregation. All reserves assigned in the Reserves Report are
located onshore in the Republic of Trinidad and Tobago and
presented on a consolidated basis.
The recovery and reserve estimates of
Touchstone's crude oil, NGL and natural gas reserves provided
herein are estimates only, and there is no guarantee that the
estimated reserves will be recovered. Actual reserves may
eventually prove to be greater than or less than the estimates
provided herein. There are numerous uncertainties inherent in
estimating quantities of petroleum and natural gas reserves and the
future cash flows attributed to such reserves. The reserve and
associated cash flow information set forth herein are estimates
only. This announcement summarizes the crude oil, NGL and natural
gas reserves of the Company and the net present values of future
net revenue for such reserves using forecast prices and costs as at
December 31, 2023 prior to provision for interest and finance
costs, general and administration expenses, and the impact of any
financial derivatives. It should not be assumed that the estimates
of future net revenues presented herein represent the fair market
value of the reserves. There is no assurance that the forecast
prices and costs assumptions will be attained, and variances could
be material.
In the Reserves Report, GLJ
forecasted reserve volumes and future cash flows based upon current
and historical well performance through to the economic production
limit of individual wells. Notwithstanding established precedence
and contractual options for the continuation and renewal of the
Company's existing licence, sub-licence and
marketing agreements, in many cases the
forecasted economic limit of individual wells is beyond the current
term of the relevant agreements. There is
no certainty as to any renewal of the Company's existing
exploration, production, and marketing arrangements.
"Proved Developed Producing"
reserves are those reserves that are expected to be recovered from
completion intervals open at the time of the estimate. These
reserves may be currently producing, or if shut-in, they must have
previously been on production, and the date of resumption of
production must be known with reasonable certainty.
"Proved" reserves are those reserves
that can be estimated with a high degree of certainty to be
recoverable. It is likely that the actual remaining quantities
recovered will exceed the estimated proved reserves.
"Probable" reserves are those
additional reserves that are less certain to be recovered than
proved reserves. It is equally likely that the actual
remaining quantities recovered will be greater or less than the sum
of the estimated proved plus probable reserves.
"Possible" reserves are those
additional reserves that are less certain to be recovered than
probable reserves. There is a 10 percent probability that the
quantities actually recovered will equal or exceed the sum of
proved plus probable plus possible reserves. It is unlikely that
the actual remaining quantities recovered will exceed the sum of
the estimated proved plus probable plus possible
reserves.
Certain terms used in this
announcement but not defined are defined in NI 51-101, CSA Staff
Notice 51-324 - Revised Glossary
to NI 51-101 Standards of
Disclosure for Oil and Gas Activities ("CSA 51-324") and/or
the COGE Handbook and, unless the context otherwise requires, shall
have the same meanings herein as in NI 51-101, CSA 51-324 and the
COGE Handbook, as the case may be.
Oil and Gas
Measures
Where applicable, natural gas has
been converted to barrels of oil equivalent (boe) based on six
thousand cubic feet (Mcf) to one barrel (bbl) of oil. The barrel of
oil equivalent rate is based on an energy equivalent conversion
method primarily applicable at the burner tip and given that the
value ratio based on the current price of crude oil as compared to
natural gas is significantly different than the energy equivalency
of the 6:1 conversion ratio, utilizing the 6:1 conversion ratio may
be misleading as an indication of value. This conversion factor is
an industry accepted norm and is not based on either energy content
or prices.
Oil and Gas
Metrics
This announcement contains several
oil and gas metrics that are commonly used in the oil and gas
industry such as reserves additions (reductions), reserve life
index ("RLI"), finding and development costs, and recycle ratio.
These metrics have been prepared by Management and do not have
standardized meanings or standardized methods of calculation, and
therefore such measures may not be comparable to similar measures
presented by other companies and should not be used to make
comparisons. Such metrics have been included herein to provide
readers with additional measures to evaluate the Company's
performance; however, such measures are not reliable indicators of
the future performance of the Company, and future performance may
not compare to the performance in prior periods, and therefore such
metrics should not be unduly relied upon. The Company uses these
oil and gas metrics for its own performance measurements and to
provide shareholders with measures to compare the Company's
operations over time. Readers are cautioned that the information
provided by these metrics, or that can be derived from the metrics
presented in this announcement, should not be relied upon for
investment purposes.
Reserve additions (reductions) are
calculated as the change in reserves from the beginning to the end
of the applicable period excluding period production. Management
uses this measure to determine the relative change of its reserves
base over a period of time.
RLI is calculated by dividing the
applicable reserves by forecasted 2024 production volumes derived
from the Reserve Report.
F&D costs represent the costs of
exploration and development incurred (refer to "Advisories:
Non-GAAP Financial
Measures"). Specifically, F&D costs are calculated as
the sum of exploration and development capital expenditures
incurred in the period and the change in future development costs
required to develop those reserves. The Company's annual audit of
its December 31, 2023 consolidated financial statements is not
complete. Accordingly, unaudited exploration and development
capital expenditure amounts used in the calculation of F&D
costs are Management's estimates and are subject to change. F&D
costs per barrel is determined by dividing current period reserve
additions to the corresponding period's F&D costs. Readers are
cautioned that the aggregate of capital expenditures incurred in
the most recent financial year and the change during that year in
estimated FDC generally will not reflect total F&D costs
related to reserves additions for that year. Management uses
F&D costs as a measure of its ability to execute its capital
program, the success in doing so, and of the Company's asset
quality.
Recycle ratio is a measure used by
Management to evaluate the effectiveness of its capital
reinvestment program and is calculated by dividing the annual
F&D costs per barrel to operating netback per barrel
prior to realized gains or losses on commodity
derivative contracts in the corresponding period (refer to
"Advisories: Non-GAAP Financial Measures"). The
Company's annual audit of its December 31, 2023 consolidated
financial statements is not complete. Accordingly, unaudited
operating netbacks used in calculations of recycle ratios are
Management's estimates and are subject to change. The recycle ratio
compares netbacks from existing reserves to the cost of finding new
reserves and may not accurately indicate the investment success
unless the replacement of reserves are of equivalent quality as the
produced reserves.
Unaudited Financial
Information
Certain annual 2023 financial
information disclosed herein including capital expenditures and
operating netback are based on unaudited estimated results and are
subject to the same limitations as discussed in the forward-looking
statements advisory disclosed herein. These estimated results are
subject to change upon completion of the Company's audited
financial statements for the year ended December 31, 2023, and
changes could be material. Touchstone anticipates filing its
audited consolidated financial statements and related management's
discussion and analysis for the year ended December 31, 2023 on
SEDAR+ (www.sedarplus.ca) on March 21, 2024.
Supplemental Information
Regarding Product Types
This announcement includes
references to fourth quarter and annual 2023 average daily
production. The following table provides production by product type
composition as defined by NI 51-101.
Period
|
Light and Medium Crude Oil
(bbls/d)
|
Heavy Crude
Oil
(bbls/d)
|
Conventional
Natural Gas
(Mcf/d)
|
Natural Gas Liquids
(bbls/d)
|
Total Oil Equivalent
(boe/d)
|
|
|
|
|
|
|
Fourth quarter of 2023
|
1,068
|
65
|
40,491
|
622
|
8,504
|
Annual 2023
|
1,113
|
68
|
15,593
|
201
|
3,981
|
|
|
|
|
|
|
In this announcement, any
references to "crude oil" refer to "light
crude oil and medium crude oil" and "heavy crude oil" combined
product types; references to "NGLs" refer to condensate; and
references to "natural gas" refer to the "conventional natural gas"
product type, all as defined in NI 51-101. Any references to "crude
oil and liquids" herein include crude oil and NGLs.
Non-GAAP Financial
Measures
This announcement may
reference various non-GAAP financial measures, non-GAAP ratios,
capital management measures and supplementary financial measures as
such terms are defined in National Instrument 52-112 -
Non-GAAP
and Other Financial Measures Disclosure. Such measures are not
recognized measures under GAAP and do not have a standardized
meaning prescribed by International Financial Reporting Standards
("IFRS" or "GAAP") and therefore may not be comparable to similar
financial measures disclosed by other issuers. Readers are
cautioned that the non-GAAP financial measures referred to herein
should not be construed as alternatives to, or more meaningful
than, measures prescribed by IFRS, and they are not meant to
enhance the Company's reported financial performance or position.
These are complementary measures that are commonly used in the oil
and natural gas industry and by the Company to provide shareholders
and potential investors with additional information regarding the
Company's performance. Non-GAAP financial measures presented herein
include operating netback, capital expenditures, F&D costs and
recycle ratio.
The Company uses
operating netback as a key performance indicator of field results.
The Company considers operating netback to be a key measure as it
demonstrates Touchstone's profitability relative to current
commodity prices and assists Management and investors with
evaluating operating results on a historical basis. Operating
netback is a non-GAAP financial measure calculated by deducting
royalties and operating expenses from petroleum and natural gas
sales. The most directly comparable financial measure to operating
netback disclosed in the Company's consolidated financial
statements is petroleum and natural gas revenue net of royalties.
Operating netback per boe is a non-GAAP ratio calculated by
dividing the operating netback by total production volumes for the
period. Presenting operating netback on a per boe basis allows
Management to better analyze performance against prior periods on a
comparable basis. The following table presents the computation of
estimated operating netback disclosed herein, using unaudited
financial information for the year ended December 31, 2023 in both
periods presented.
($000's unless otherwise stated)
|
|
|
Year ended December 31,
2023
|
Five years ended December 31,
2023
|
|
|
|
|
|
Petroleum and natural gas
sales
|
|
|
48,098
|
178,856
|
Less: royalties
|
|
|
(12,173)
|
(52,539)
|
Petroleum and natural gas revenue, net of
royalties
|
|
35,925
|
126,317
|
Less: operating expenses
|
|
|
(9,705)
|
(42,647)
|
Estimated operating netback
|
|
|
26,220
|
83,670
|
Production (boe)
|
|
|
1,453,073
|
3,698,125
|
Estimated operating netback ($/boe)
|
|
|
18.04
|
22.62
|
Capital expenditures is a non-GAAP
financial measure that is calculated as the sum of exploration and
evaluation asset expenditures and property, plant and equipment
expenditures included in the Company's consolidated statements of
cash flows and is most directly comparable
to cash flows used in investing activities. Touchstone considers
capital expenditures to be a useful measure of its investment in
its existing asset base. The following table presents the
computation of estimated capital expenditures disclosed herein,
using unaudited financial information for the year ended December
31, 2023 in both periods presented.
($000's)
|
|
Year ended December 31,
2023
|
Five years ended December 31,
2023
|
|
|
|
|
Exploration and evaluation asset
expenditures
|
|
17,638
|
75,506
|
Property, plant and equipment
expenditures
|
|
1,311
|
12,707
|
Estimated capital expenditures
|
|
18,949
|
88,213
|
Refer to "Advisories: Oil and Gas Metrics"
regarding F&D costs and recycle ratio.
Abbreviations
bbl(s)
barrel(s)
bbls/d
barrels per day
Mbbl
thousand barrels
Mcf
thousand cubic feet
MMcf
million cubic feet
MMBtu
million British Thermal Units
NGL(s)
natural gas liquid(s)
boe
barrels of oil equivalent
boe/d
barrels of oil equivalent per day
Mboe
thousand barrels of oil equivalent
Competent Persons Statement
In
accordance with the AIM Rules for Companies, the technical
information contained in this announcement has been reviewed and
approved by James Shipka, Chief Operating Officer of Touchstone
Exploration Inc. Mr. Shipka is a qualified person as defined in the
London Stock Exchange's Guidance Note for Mining and Oil and Gas
Companies and is a Fellow of the Geological Society of London (BGS)
as well as a member of the Canadian Society of Petroleum Geologists
and the Geological Society of Trinidad and Tobago. Mr. Shipka has a
Bachelor of Science in Geology from the University of Calgary and
has over 30 years of oil and gas exploration and development
experience.