PDP Reserves up 55% to 44 mmboe
1P Reserves up 17% to 114 mmboe Valued at $1.8 Billion
2P Reserves up 15% to 184 mmboe Valued at $2.7 Billion
3P Reserves Up 44% to 347 mmboe Valued at $5.1 Billion
2P Reserve Replacement of 285%
2P Value Per Share (Net Debt-Adjusted) up 37% to $40.1 Per Share
GeoPark Limited (“GeoPark” or the “Company”) (NYSE: GPRK), a leading
independent Latin American oil and gas explorer, operator and
consolidator with operations and growth platforms in Colombia, Peru,
Argentina, Brazil and Chile, today announced its independent oil and gas
reserves assessment, certified by DeGolyer and MacNaughton Corp. (D&M),
under PRMS methodology, as of December 31, 2018.
This press release features multimedia. View the full release here:
https://www.businesswire.com/news/home/20190205005362/en/
(Photo: Business Wire)
All figures are expressed in US Dollars. Definitions of terms are
provided in the Glossary on page [12].
Year-End 2018 D&M Certified Oil and Gas Reserves and Highlights:
After consolidated capital expenditures of $2.9 per share in 2018:
-
Net debt-adjusted 2P NPV10 increase of $10.9 per share (3.8 times
higher) to $40.1 per share, from $29.2 per share in 2017
-
Significant increase in Colombia’s net debt adjusted 2P NPV10 by 64%
to $25.9 per share, from $15.8 per share in 2017, with capital
expenditures of $1.6 per share
-
Accretive acquisition of LGI’s equity interest in GeoPark’s Colombian
and Chilean subsidiaries for $2 per share, with a 2018 estimated 2P
NPV10 of $4 per share
-
PDP Reserves:
-
Net proven developed producing (“PDP”) reserves increased 55% (by
15.7 mmboe) to 44.2 mmboe
-
PDP reserve life index (“RLI”) of 3.3 years
-
PDP reserve replacement ratio ("RRR") of 218%
-
1P Reserves:
-
Net proven (“1P”) reserves increased 17% (by 16.9 mmboe) to 113.9
mmboe
-
1P RLI of 8.6 years
-
1P RRR of 229%
-
1P NPV10 increased by $268 million (up 17%) to $1.8 billion
-
2P Reserves:
-
Net proven and probable (“2P”) reserves increased 15% (by 24.5
mmboe) to 183.7 mmboe
-
2P RLI of 13.9 years
-
2P RRR of 285%
-
2P NPV10 increased by $454 million (up 20%) to $2.7 billion
-
Colombia 2P and 3P Reserves:
-
Net 2P reserves in Colombia increased 26% (by 23.0 mmboe) to 111.2
mmboe
-
2P RLI of 10.7 years
-
2P RRR of 321%
-
2P NPV10 in Colombia increased by $491 million (up 35%) to $1.9
billion
-
Net 3P reserves in Colombia increased 43% (by 43.9 mmboe) to 145.6
mmboe
-
Peru 3P Reserves:
-
Gross 3P reserves in Peru increased 139% (by 115.3 mmbbl) to 198.3
mmbbl demonstrating the significant potential of the Situche
Cntral field in the Morona block - with net 3P reserves of 131.2
mmbbl
-
3P NPV10 in Peru increased by $1.1 billion (up 145%) to $1.9
billion
-
F&D Cost:
-
Finding and Development Cost (F&D Cost) for 2018 was $3.6 per boe
on a 2P basis
-
F&D Cost for Colombia of $2.9 per boe on a 2P basis
-
Including the acquisition in Argentina, consolidated Finding,
Development and Acquisition Cost (FD&A Cost) for 2018 was $3.6 per
boe on a 2P basis
James F. Park, Chief Executive Officer of GeoPark, said: “Again, our
team did its job. Find, prove-up, develop and produce oil and gas -
safely, cleanly and economically. The reserve certification is an
important independent scorecard of an upstream company’s performance -
and all elements of our report show major improvements across the board
through 2018. Impressive growing oil and gas reserve volumes - strong
reserve replacement metrics - large asset value increases - cheap
Finding and Development Cost - and big bottom-line ‘per share’ value
growth. Our Colombian Llanos 34 prize keeps getting more massive with
even more opportunity for expansion. Furthermore, every category of
reserve was certified with significant increases - demonstrating
GeoPark’s short, medium and long-term depth, stability and potential.
The report also highlights GeoPark’s unique oil and gas and regional
asset platform - which is made real by our relentless 16-year
performance growth track record - showing our team has, can and will
continue to deliver results, meet challenges, and adapt and grow to
capture our abundant opportunity set. Congratulations and many thanks to
the women and men of GeoPark - the most dynamic oil and gas team in
Latin America today.”
Net Present Value per Share by Country
The table below presents GeoPark’s net present value after tax and
non-controlling interest, discounted at a 10% rate per share, by
country, of 2P reserves as of December 31, 2018 and 2017.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2018 Net Present Value per Share
|
|
|
Colombia
|
|
Peru
|
|
Chile
|
|
Argentina
|
|
Brazil
|
|
Total
|
2P Reserves (mmboe)
|
|
|
111.2
|
|
30.3
|
|
24.7
|
|
14.2
|
|
3.2
|
|
183.7
|
2P NPV10 2018 ($ mm)
|
|
|
1,884
|
|
410
|
|
306
|
|
93
|
|
52
|
|
2,745
|
Shares Outstanding (mm)
|
|
|
60.5
|
|
60.5
|
|
60.5
|
|
60.5
|
|
60.5
|
|
60.5
|
($/share)
|
|
|
31.2
|
|
6.8
|
|
5.1
|
|
1.5
|
|
0.9
|
|
45.4
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The table below illustrates the details of the net debt adjusted 2P
NPV10 per share which increased by 37% to $40.1 from $29.2 in 2017.
|
|
|
|
|
|
|
|
Net Debt Adjusted 2P NPV10 per Share
|
|
|
Total 2018
|
|
Total 2017
|
|
% Change
|
2P NPV10 ($ mm)
|
|
|
2,745
|
|
2,291
|
|
|
Non-controlling Interesta ($ mm)
|
|
|
-
|
|
-228
|
|
|
Subtotal ($ mm)
|
|
|
2,745
|
|
2,063
|
|
|
Shares Outstanding (mm)
|
|
|
60.5
|
|
60.6
|
|
|
Subtotal ($/share)
|
|
|
45.4
|
|
34.0
|
|
34%
|
Net Debtb/Share ($/share)
|
|
|
-5.3
|
|
-4.8
|
|
|
Net Debt Adjusted 2P NPV10 /Share ($/share)
|
|
|
40.1
|
|
29.2
|
|
37%
|
|
|
|
|
|
|
|
|
|
a)
|
|
Non-controlling interest refers to LGI participation in Chilean and
Colombian subsidiaries. In November 2018, GeoPark acquired all
outstanding LGI participation for $111 million plus three contingent
payments of $5 million each that could be payable over the next
three years, subject to certain production thresholds being exceeded.
|
|
b)
|
|
Net debt adjusted 2P NPV10 per share is shown on a consolidated
basis. As of December 31, 2018, net debt is calculated considering
unaudited financial debt of $446.7 million, less unaudited $127.7
million of cash and cash equivalents.
|
Consolidated Reserve Life Index and Replacement Ratio
|
|
|
|
|
Reserves Category
|
|
December 2018
|
|
December 2017
|
Consolidated (years)
|
|
|
|
|
RLI PDP
|
|
3.3
|
|
2.8
|
RLI 1P
|
|
8.6
|
|
9.5
|
RLI 2P
|
|
13.9
|
|
15.6
|
RLI 3P
|
|
26.2
|
|
23.7
|
RRR PDP
|
|
218%
|
|
189%
|
RRR 1P
|
|
229%
|
|
284%
|
RRR 2P
|
|
285%
|
|
261%
|
RRR 3P
|
|
899%
|
|
166%
|
2018 Year-End Reserves Summary
GeoPark engaged D&M to carry out an independent appraisal of reserves as
of December 31, 2018, covering 100% of the current assets in Colombia,
Chile, Brazil, Peru and Argentina. Following oil and gas production of
13.2 mmboe in 2018, D&M certified 2P net reserves of 183.7 mmboe (85%
oil and 15% gas) as of December 31, 2018. By country, the reserves were:
61% in Colombia, 17% in Peru, 13% in Chile, 7% in Argentina and 2% in
Brazil.
Reserves Summary by Country and Category
|
|
|
|
|
|
|
|
|
|
|
Country
|
|
Reserves Category
|
|
December 2018 (mmboe)
|
|
% Oil
|
|
December 2017 (mmboe)
|
|
% Change
|
Colombiaa
|
|
PDP
|
|
34.7
|
|
99%
|
|
21.6
|
|
61%
|
|
|
1P
|
|
79.5
|
|
100%
|
|
66.1
|
|
20%
|
|
|
2P
|
|
111.2
|
|
100%
|
|
88.2
|
|
26%
|
|
|
3P
|
|
145.6
|
|
100%
|
|
101.7
|
|
43%
|
Peru
|
|
PDP
|
|
-
|
|
100%
|
|
-
|
|
N/A
|
|
|
1P
|
|
18.5
|
|
100%
|
|
18.7
|
|
-1%
|
|
|
2P
|
|
30.3
|
|
100%
|
|
31.5
|
|
-4%
|
|
|
3P
|
|
131.2
|
|
100%
|
|
62.2
|
|
111%
|
Chile
|
|
PDP
|
|
2.8
|
|
25%
|
|
2.6
|
|
9%
|
|
|
1P
|
|
7.2
|
|
48%
|
|
7.9
|
|
-9%
|
|
|
2P
|
|
24.7
|
|
39%
|
|
34.0
|
|
-27%
|
|
|
3P
|
|
37.9
|
|
40%
|
|
66.6
|
|
-43%
|
Argentina
|
|
PDP
|
|
3.5
|
|
62%
|
|
0.0
|
|
N/A
|
|
|
1P
|
|
5.7
|
|
63%
|
|
0.0
|
|
N/A
|
|
|
2P
|
|
14.2
|
|
44%
|
|
1.1
|
|
1191%
|
|
|
3P
|
|
28.9
|
|
47%
|
|
6.4
|
|
352%
|
Brazil
|
|
PDP
|
|
3.1
|
|
2%
|
|
4.3
|
|
-28%
|
|
|
1P
|
|
3.1
|
|
2%
|
|
4.3
|
|
-28%
|
|
|
2P
|
|
3.2
|
|
2%
|
|
4.4
|
|
-27%
|
|
|
3P
|
|
3.4
|
|
2%
|
|
4.6
|
|
-26%
|
Total (D&M Certified)
|
|
PDP
|
|
44.2
|
|
85%
|
|
28.5
|
|
55%
|
|
|
1P
|
|
113.9
|
|
92%
|
|
97.0
|
|
17%
|
|
|
2P
|
|
183.7
|
|
85%
|
|
159.2
|
|
15%
|
|
|
3P
|
|
347.0
|
|
88%
|
|
241.6
|
|
44%
|
|
a)
|
|
GeoPark signed an agreement to divest the La Cuerva and Yamu
blocks. The table above includes 1.1 mmboe, 2.3 mmboe, 5.3 mmboe
and 7.9 mmboe of PDP, 1P, 2P and 3P reserves as of December 31,
2018, respectively in the La Cuerva and Yamu blocks.
|
Analysis by Business Segment
Colombia
After record production of 10.8 mmbbl in 2018 (an increase of 30% over
2017), GeoPark’s 2P D&M certified reserves increased by 26% to 111.2
mmbbl compared to 2017. Net additions of 33.4 mmbbl of 2P reserves
resulted from strong reservoir performance and continued successful
exploration, development and appraisal drilling in the Llanos 34 block
(GeoPark operated, 45% WI).
For each barrel of oil extracted in Colombia, GeoPark added 2.3 barrels
of 1P reserves, the equivalent of a 1P RRR of 229%. Similarly, for each
barrel of oil extracted, GeoPark added 3.2 barrels of 2P reserves,
resulting in a 2P RRR of 321%.
The 1P RLI was 7.6 years, while the 2P RLI was 10.7 years.
As of December 31, 2018, the Llanos 34 block included approximately
80-90 future development drilling locations (2P, gross, including the
Mirador and Guadalupe formations). The Llanos 34 block represented 95%
of GeoPark Colombia 2P D&M certified reserves as of December 31, 2018.
In November 2018, GeoPark signed an agreement with Perenco Oil and Gas
to divest the La Cuerva and Yamu blocks for $18 million plus a
contingent payment of $2 million based on future oil prices. GeoPark
will continue operating the La Cuerva and Yamu blocks until the closing
of this transaction, expected in the first months of 2019. Reserves
corresponding to the La Cuerva and Yamu blocks include 2.3 mmboe of 1P
(1.1 mmboe PD and 1.2 mmboe PUD), 5.3 mmboe of 2P and 7.9 mmboe of 3P
reserves as of December 31, 2018.
Peru
GeoPark completed the preparation of the Environmental Impact Assessment
(EIA) to initiate operations in the Situche Central oil field in the
Morona block (GeoPark operated, 75% WI). The EIA was submitted to the
Servicio Nacional de Certificacion Ambiental (SENACE) on July 2, 2018.
The Company is currently waiting for additional comments from SENACE,
which is the final step of the EIA approval process.
During 2018, D&M updated its review of the Situche Central field,
including a reinterpretation of the 3D seismic, structural geology,
trapping and oil migration model. Following this evaluation, D&M has
certified 3P gross reserves of 198.3 mmbbl in the Situche Central field
(131.2 mmbbl net to GeoPark), which represents a 111% increase with
respect to the 2017 reserve certification, and provides more information
with respect to the field size and significant upside potential.
The Situche Central oil field in the Morona block represented 100% of
GeoPark’s Peruvian D&M certified reserves.
Chile
GeoPark’s 2P D&M certified reserves in Chile decreased by 27% to 24.7
mmboe compared to 2017. Oil and gas production, adjusted development
plans and other technical revisions caused the declines, which were
partially offset by drilling successes.
The 1P RLI was 7.2 years (no change from 2017). The 2P RLI decreased to
24.7 years, compared to 30.7 years in 2017.
The Fell block represented 99% of GeoPark Chile 2P D&M certified
reserves and consisted of 40% oil and 60% gas, similar to 2017.
Argentina
After production of 0.7 mmboe in 2018, GeoPark’s 2P D&M certified
reserves in Argentina increased significantly to 14.2 mmboe compared to
1.1 mmboe in 2017. The net increase in 2018 includes the acquisition of
100% WI and operatorship of the Aguada Baguales, El Porvenir and Puesto
Touquet blocks.
The 1P RLI and 2P RLI increased to 6.1 years and 15.2 years,
respectively.
The Aguada Baguales, El Porvenir and Puesto Touquet blocks represented
91% of GeoPark Argentina 2P D&M certified reserves and consisted of 42%
oil and 58% gas.
Brazil
GeoPark’s 2P D&M certified reserves in Brazil decreased by 27% to 3.2
mmboe compared to 2017, resulting from production of 1.1 mmboe during
2018.
The 2P RLI decreased to 2.9 years compared to 4.0 years in 2017.
The Manati field (GeoPark non-operated, 10% WI) represented 100% of
GeoPark’s Brazilian D&M certified reserves and is 98% gas.
D&M Net Certified Reserves Change by Country
The following table shows the net change in 2P net reserves by country
from December 31, 2017 to December 31, 2018:
|
|
|
|
|
|
|
|
|
|
|
|
|
(mmboe)
|
|
Colombia
|
|
Peru
|
|
Chile
|
|
Argentina
|
|
Brazil
|
|
Total
|
2P Net Reserves as of Dec. 31, 2017
|
|
88.2
|
|
31.5
|
|
34.0
|
|
1.1
|
|
4.4
|
|
159.2
|
2018 Production
|
|
-10.4
|
|
0.0
|
|
-1.0
|
|
-0.7
|
|
-1.1
|
|
-13.2
|
Net Change
|
|
33.4
|
|
-1.2
|
|
-8.3
|
|
-
|
|
-0.1
|
|
23.9
|
Acquisitions
|
|
-
|
|
-
|
|
-
|
|
13.8
|
|
-
|
|
13.8
|
2P Net Reserves as of Dec. 31, 2018
|
|
111.2
|
|
30.3
|
|
24.7
|
|
14.2
|
|
3.2
|
|
183.7
|
Net Present Value Summary
The table below details D&M certified NPV10 by country and by category
of reserves as of December 31, 2018 as compared to 2017:
|
|
|
|
|
|
|
|
|
Country
|
|
Reserves Category
|
|
NPV10 2018
|
|
NPV10 2017
|
|
|
|
|
($ mm)
|
|
($ mm)
|
|
% Change
|
Colombia
|
|
1P
|
|
1,366
|
|
1,123
|
|
|
|
|
2P
|
|
1,884
|
|
1,393
|
|
|
|
|
3P
|
|
2,394
|
|
1,588
|
|
|
Peru
|
|
1P
|
|
264
|
|
230
|
|
|
|
|
2P
|
|
410
|
|
395
|
|
|
|
|
3P
|
|
1,896
|
|
773
|
|
|
Chile
|
|
1P
|
|
94
|
|
120
|
|
|
|
|
2P
|
|
306
|
|
417
|
|
|
|
|
3P
|
|
495
|
|
707
|
|
|
Argentina
|
|
1P
|
|
44
|
|
1
|
|
|
|
|
2P
|
|
93
|
|
7
|
|
|
|
|
3P
|
|
262
|
|
90
|
|
|
Brazil
|
|
1P
|
|
49
|
|
76
|
|
|
|
|
2P
|
|
52
|
|
78
|
|
|
|
|
3P
|
|
56
|
|
82
|
|
|
Total
|
|
1P
|
|
1,817
|
|
1,549
|
|
17%
|
(D&M Certified)
|
|
2P
|
|
2,745
|
|
2,291
|
|
20%
|
|
|
3P
|
|
5,103
|
|
3,240
|
|
58%
|
Oil Price Forecast
The price assumptions used to estimate feasibility of PRMS reserves and
NPV10 in 2018 and 2017 D&M reports are detailed in the table below:
|
|
|
|
|
|
|
|
|
|
|
|
|
Brent Oil Price
($/bbl)
|
|
2019
|
|
2020
|
|
2021
|
|
2022
|
|
2023
|
|
2024- 2026
|
|
|
|
|
|
|
2018 Reserves Report
|
|
63.9
|
|
68.2
|
|
71.0
|
|
73.4
|
|
75.4
|
|
77.4-81.6
|
2017 Reserves Report
|
|
62.0
|
|
65.0
|
|
68.1
|
|
71.6
|
|
74.3
|
|
78.1-84.6
|
After 2026, Brent oil prices in the 2018 D&M report grow 2% per year.
Total D&M Certified Future Net Revenue (Actual and Discounted)
The table below presents D&M’s best estimate of GeoPark's future net
revenue (both actual and discounted at a 10% rate) and the unit value
per boe, by country, and by category of certified reserves as of
December 31, 2018:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
($ mm)
|
|
Oil and Gas Revenues
|
|
Royalties
|
|
Operating Costs
|
|
Future Development Capital and Abandonment Costs
|
|
Income Tax
|
|
Future Net Revenue after tax
|
|
Future Net Revenue after tax discounted at
10%
|
|
Unit Value after tax discounted at
10% ($/boe)
|
Colombia1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1P
|
|
4,320
|
|
611
|
|
543
|
|
208
|
|
872
|
|
2,086
|
|
1,366
|
|
$17
|
2P
|
|
6,120
|
|
877
|
|
715
|
|
288
|
|
1,259
|
|
2,981
|
|
1,884
|
|
$17
|
3P
|
|
8,142
|
|
1,280
|
|
904
|
|
349
|
|
1,675
|
|
4,935
|
|
2,394
|
|
$16
|
Peru
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1P
|
|
1,428
|
|
81
|
|
365
|
|
294
|
|
212
|
|
476
|
|
264
|
|
$14
|
2P
|
|
2,467
|
|
141
|
|
624
|
|
415
|
|
392
|
|
895
|
|
410
|
|
$14
|
3P
|
|
11,384
|
|
1,248
|
|
1,591
|
|
1,345
|
|
2,157
|
|
5,043
|
|
1,896
|
|
$15
|
Chile
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1P
|
|
341
|
|
15
|
|
154
|
|
39
|
|
4
|
|
129
|
|
94
|
|
$13
|
2P
|
|
1,107
|
|
46
|
|
369
|
|
159
|
|
66
|
|
467
|
|
306
|
|
$12
|
3P
|
|
1,733
|
|
73
|
|
500
|
|
222
|
|
127
|
|
811
|
|
495
|
|
$13
|
Argentina
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1P
|
|
298
|
|
56
|
|
123
|
|
54
|
|
7
|
|
58
|
|
43
|
|
$8
|
2P
|
|
662
|
|
125
|
|
184
|
|
176
|
|
36
|
|
141
|
|
93
|
|
$7
|
3P
|
|
1,432
|
|
269
|
|
292
|
|
262
|
|
147
|
|
462
|
|
262
|
|
$9
|
Brazil
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1P
|
|
113
|
|
9
|
|
39
|
|
4
|
|
5
|
|
56
|
|
49
|
|
$16
|
2P
|
|
118
|
|
9
|
|
39
|
|
4
|
|
5
|
|
61
|
|
52
|
|
$16
|
3P
|
|
125
|
|
10
|
|
39
|
|
4
|
|
6
|
|
66
|
|
56
|
|
$16
|
Total
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1P
|
|
6,500
|
|
772
|
|
1,224
|
|
599
|
|
1,100
|
|
2,805
|
|
1,817
|
|
$16
|
2P
|
|
10,474
|
|
1,198
|
|
1,931
|
|
1,042
|
|
1,758
|
|
4,545
|
|
2,745
|
|
$15
|
3P
|
|
22,817
|
|
2,880
|
|
3,326
|
|
2,182
|
|
4,112
|
|
10,317
|
|
5,103
|
|
$15
|
1 Oil and gas revenues in Colombia are shown net of
earn-out expenses, per IFRS rules, of $180 mm (1P), $250 mm (2P) and
$325 mm (3P). D&M reported these expenses as operating costs.
|
Finding and Development Cost by Reserves Category
The table below sets forth the calculation of F&D and FD&A Cost as of
December 31, 2018:
|
|
|
|
|
December 31, 2018
|
|
|
1P
|
|
2P
|
|
Colombia 1P
|
|
Colombia 2P
|
Capital Expenditure/Acquisitions (unaudited) ($ mm)
|
|
124.7
|
|
124.7
|
|
97.0
|
|
97.0
|
Reserve Additions (mmboe)
|
|
24.5
|
|
34.5
|
|
23.8
|
|
33.4
|
Argentina Acquisition F&D Cost ($ mm)
|
|
48.8
|
|
48.8
|
|
-
|
|
-
|
Argentina Reserves (mmboe)
|
|
5.2
|
|
13.8
|
|
-
|
|
-
|
F&D Cost ($/boe)
|
|
5.1
|
|
3.6
|
|
4.1
|
|
2.9
|
FD&A Cost ($/boe)
|
|
5.8
|
|
3.6
|
|
|
|
|
OTHER NEWS / RECENT EVENTS
Reporting Date for 4Q2018 Results Release, Conference Call and Webcast
GeoPark will report its 4Q2018 and Annual 2018 financial results on
Wednesday, March 6, 2019 after the market close.
In conjunction with 4Q2018 results press release, GeoPark’s management
will host a conference call on March 7, 2019 at 9:00 am (Eastern
Standard Time) to discuss these 4Q2018 financial results. To listen to
the call, participants can access the webcast located in the Investor
Support section of the Company’s website at www.geo-park.com.
Interested parties may participate in the conference call by dialing the
numbers provided below:United States
Participants: 866-547-1509
International Participants: +1
920-663-6208
Passcode: 4069004
Please allow extra time prior to the call to visit the website and
download any streaming media software that might be required to listen
to the webcast.
An archive of the webcast replay will be made available in the Investor
Support section of the Company’s website at www.geo-park.com
after the conclusion of the live call.
|
GLOSSARY
|
|
1P
|
|
|
Proven Reserves
|
|
|
|
|
2P
|
|
|
Proven plus Probable Reserves
|
|
|
|
|
3P
|
|
|
Proven plus Probable plus Possible Reserves
|
|
|
|
|
boe
|
|
|
Barrels of oil equivalent (6,000 cf gas per bbl of oil equivalent)
|
|
|
|
|
boepd
|
|
|
Barrels of oil equivalent per day
|
|
|
|
|
bopd
|
|
|
Barrels of oil per day
|
|
|
|
|
Certified Reserves
|
|
|
Refers to net reserves independently evaluated by the petroleum
consulting firm, DeGolyer and MacNaughton Corp. (“D&M”)
|
|
|
|
|
F&D Cost
|
|
|
Finding and Development Cost, calculated as the unaudited cash
flow from investing activities divided by the applicable net
reserves additions before changes in Future Development Capital
|
|
|
|
|
FD&A Cost
|
|
|
Finding, Development and Acquisition Cost, calculated as the
unaudited cash flow from investing activities plus acquisition
costs divided by the applicable net reserves additions before
changes in Future Development Capital
|
|
|
|
|
mboed
|
|
|
Thousands of Barrels of oil equivalent per day
|
|
|
|
|
mmboed
|
|
|
Millions of Barrels of oil equivalent per day
|
|
|
|
|
mmbbl
|
|
|
Millions of Barrels of oil
|
|
|
|
|
mcfpd
|
|
|
Thousands of standard cubic feet per day
|
|
|
|
|
mmcfpd
|
|
|
Millions of standard cubic feet per day
|
|
|
|
|
NPV10
|
|
|
Net Present Value after tax discounted at 10% rate
|
|
|
|
|
PDNP
|
|
|
Proven Developed Non-Producing Reserves
|
|
|
|
|
PDP
|
|
|
Proven Developed Producing Reserves
|
|
|
|
|
PUD
|
|
|
Proven Undeveloped Reserves
|
|
|
|
|
RLI
|
|
|
Reserve Life Index
|
|
|
|
|
RRR
|
|
|
Reserve Replacement Ratio
|
|
|
|
|
sqkm
|
|
|
Square kilometers
|
|
|
|
|
WI
|
|
|
Working Interest
|
|
|
|
|
NOTICE
Additional information about GeoPark can be found in the “Investor
Support” section of the website at www.geo-park.com.
The reserve estimates provided in this release 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. Statements relating to reserves are by
their nature forward-looking statements.
Gas quantities estimated herein are reserves to be produced from the
reservoirs, available to be delivered to the gas pipeline after field
separation prior to compression. Gas reserves estimated herein includes
fuel gas.
Rounding amounts and percentages: Certain amounts and percentages
included in this press release have been rounded for ease of
presentation. Percentage figures included in this press release have not
in all cases been calculated on the basis of such rounded figures, but
on the basis of such amounts prior to rounding. For this reason, certain
percentage amounts in this press release may vary from those obtained by
performing the same calculations using the figures in the financial
statements. In addition, certain other amounts that appear in this press
release may not sum due to rounding.
Oil and gas production figures included in this release are stated
before the effect of royalties paid in kind, consumption and losses.
All evaluations of future net revenue contained in the D&M Reports are
after the deduction of cash royalties, development costs, operating
expenses, production and profit taxes, fees, earn out payments, well
abandonment costs, and country income taxes from the future gross
revenue. It should not be assumed that the estimates of future net
revenues presented in the tables represent the fair market value of the
reserves. The actual production, revenues, taxes and development, and
operating expenditures with respect to the reserves associated with the
Company's properties may vary, from the information presented herein,
and such variations could be material. In addition, there is no
assurance that the forecast price and cost assumptions contained in the
D&M Report will be attained, and variances could be material.
CAUTIONARY STATEMENTS RELEVANT TO FORWARD-LOOKING INFORMATION
This press release contains statements that constitute forward-looking
statements. Many of the forward looking statements contained in this
press release can be identified by the use of forward-looking words such
as ‘‘anticipate,’’ ‘‘believe’’, ‘‘could,’’ ‘‘expect,’’ ‘‘should,’’
‘‘plan,’’ ‘‘intend,’’ ‘‘will,’’ ‘‘estimate’’ and ‘‘potential,’’ among
others.
Forward-looking statements that appear in a number of places in this
press release include, but are not limited to, statements regarding the
intent, belief or current expectations, regarding various matters
including 2019 work program, NPV10 and NPV10/share estimations,
estimated future revenues and oil price forecast. Forward-looking
statements are based on management’s beliefs and assumptions, and on
information currently available to the management. Such statements are
subject to risks and uncertainties, and actual results may differ
materially from those expressed or implied in the forward-looking
statements due to various factors.
Forward-looking statements speak only as of the date they are made, and
the Company does not undertake any obligation to update them in light of
new information or future developments or to release publicly any
revisions to these statements in order to reflect later events or
circumstances, or to reflect the occurrence of unanticipated events. For
a discussion of the risks facing the Company which could affect whether
these forward-looking statements are realized, see the Company’s filings
with the U.S. Securities and Exchange Commission.
Information about oil and gas reserves: The SEC permits oil and
gas companies, in their filings with the SEC, to disclose only proven,
probable and possible reserves that meet the SEC's definitions for such
terms. GeoPark uses certain terms in this press release, such as "PRMS
Reserves" that the SEC's guidelines do not permit GeoPark from including
in filings with the SEC. As a result, the information in the Company’s
SEC filings with respect to reserves will differ significantly from the
information in this press release. NPV10 for PRMS 1P, 2P and 3P reserves
is not a substitute for the standardized measure of discounted future
net cash flows for SEC proved reserves.
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