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8-K - 8-K - Samson Resources Corp | d821269d8k.htm |
Q3 2014
Conference Call November 17, 2014
Supplemental Materials
Exhibit 99.1 |
2
Cautionary Statement Regarding Forward-Looking Statements
Non-GAAP Disclosures
Forward-Looking & Other Cautionary Statements
The information in this presentation by Samson Resources Corporation (the Company,
we or our) includes forward-looking statements within the
meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the
Securities Exchange Act of 1934, as amended. All statements included in this
presentation, other than statements of historical fact, may constitute forward-looking statements, including, but not limited to, statements
or information regarding our future growth, results of operations, operational and financial
performance, business prospects and opportunities and future events. Words such as, but
not limited to, anticipate, continue, estimate, expect, may, might, will, project, should, believe, intend,
continue, could, plan, predict,
potential, goal, foresee and negatives of these words and similar expressions are intended to identify forward-
looking statements. In particular, statements about our expectations, beliefs, plans,
objectives, assumptions or future events or performance contained in this presentation
are forward-looking statements.
All forward-looking statements involve risks and uncertainties. The occurrence of the
events described and the achievement of the expected results depend on many events and
assumptions, some or all of which are not predictable or within our control. Factors that may cause actual results to differ from
expected results include, but are not limited to: (i) fluctuations in oil and natural gas
prices; (ii) the uncertainty inherent in estimating our reserves, future net revenues
and PV-10; (iii) the timing and amount of future production of oil and natural gas; (iv) cash flow and changes in the availability and cost of
capital; (v) environmental, drilling and other operating risks, including liability claims as
a result of our oil and natural gas operations; (vi) proved and unproved drilling
locations and future drilling plans; (vii) the effects of existing and future laws and governmental regulations, including environmental,
hydraulic fracturing and climate change regulation; (viii) restrictions contained in our debt
agreements; (ix) our ability to generate sufficient cash to service our indebtedness; (x) our ability to make acquisitions and divestitures on favorable terms or at all; and (xi) any of the risk factors and other cautionary
statements described in, including under the heading Risk Factors, the prospectus
relating to the exchange offer of our senior notes, dated as of and filed with the
Securities and Exchange Commission pursuant to Rule 424(b) under the Securities Act of 1933, as amended, on July 22, 2014, and in the other
documents and reports we file from time to time with the Securities and Exchange Commission.
Readers are cautioned not to place undue reliance on forward-looking statements. Should
one or more of the risks or uncertainties referenced above occur, or should underlying
assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking
statements. Further, new factors that could cause actual results to differ materially from
those described in forward-looking statements emerge from time to time, and it is
not possible to predict all such factors, or the extent to which any such factor or combination of factors may cause actual results to differ
from those contained in any forward-looking statement.
Each forward-looking statement speaks only as of the date of this presentation, and,
except as otherwise required by applicable law, we disclaim any duty to update any
forward-looking statements, all of which are expressly qualified by the statements in this section, to reflect events or circumstances after the
date of this presentation.
This presentation refers to certain non-GAAP financial measures. Definitions of these
measures and reconciliation between U.S. GAAP and non-GAAP financial measures are
included at the end of this presentation. |
Current
Strategy Focus the Asset Base
Core
Assess
Divest/Monetize
Ft. Union
Powder River
Mid-Con
East Texas
Williston
Arkoma
San Juan
Wamsutter
3
Targeted Acquisition (New Cores Areas) |
Executing on
the Strategy 4
Material Acquisitions
Bolt-On Acquisitions
Potential Material Divestitures
Targeted Less Material Divestitures
Efforts ongoing
Focused on Eagle Ford and Permian Basin
PSA executed with Goodrich Petroleum (GDP)
to acquire Taylor producing properties and
acreage in Rusk County, Texas
Acquired additional 5,000 net acres in East
Texas (excluding GDP)
Williston
Data room process underway
Dry
Gas
Assets
San
Juan,
Wamsutter,
and
Arkoma
exploring monetization
alternatives for assets
Total 2014 divestiture proceeds expected to
exceed $150 MM for FY 2014
$114 MM closed through 9/30 |
Deal
Overview (1)
Samson agreed to acquire 38,000 net acres from
Goodrich Petroleum
Substantial and contiguous acreage block directly
offsetting our Oakhill Field in Rusk County
98% operated with over 200 gross wells currently
producing
Expected to close on December 22
nd
Deal Statistics
Purchase Price
(2)
: $61MM
$ per Proved Reserves: $1.61
$ per Mcfe/d: $4,800
Acreage: Gross 41,000 / Net 38,000
Net Production
(3)
: 12.8 MMcfe/d (20% Liquids)
Proved Reserves
(4)
: 38 Bcfe
Net Resource Potential: 100+ Bcfe
East Texas
Bolt-On Acquisition
5
(1)
The closing of the transaction is subject to certain customary terms and conditions
(2)
Subject to certain customary purchase price adjustment provisions
(3)
Three-stream production as of 10/15/2014
(4)
SEC Pricing as of 9/30/2014
Acquisition Map
Overview
HARRISON
PANOLA
RUSK
GREGG
Texas
Oklahoma
Acquired Acreage |
% Liquids Pro
Forma (2)
Total Company Pro Forma
(2)
Q314 Production Summary
6
(MMcfe/d)
(1)
Reflects certain non-core assets located throughout the United States
(2)
Excludes all divested production since 1/1/2013
Q1'14
Q2'14
Q3'14
9ME '14
9ME '13
West Division
Williston
23
24
29
25
25
Powder River
22
29
29
26
23
Greater Green River
56
64
51
57
80
San Juan
84
80
80
81
94
East Division
Mid-con West
84
84
73
80
95
Mid-con East
110
103
97
104
93
East Texas
148
157
169
158
176
Other
(1)
2
2
2
2
3
Total Company
529
543
530
533
589
516
531
525
524
556
30%
30%
30%
30%
29% |
Bakken
Encouraging results from first operated
4-well pad on increased spacing with plug & perf
completion
PRB
Focused on drilling 2 mile Sussex laterals
and assessment of upside potential in Mowry and
Frontier
Ft. Union
2014/2015 drilling program underway
with two rigs
Taylor
Strong results with five wells flowing to
sales with average IP30 of 6.5 MMcfe/d and D&C
of
$7.9MM
(7%
Liquids
(2)
)
Mississippi
Lime
Positive
results
with
five
wells
flowing to sales with average IP30 of 340 Boe/d
and
D&C
of
$4.9MM
(77%
Liquids
(2)
)
Granite Wash
Two rigs running as of mid-
November set to test multiple horizons through
single well pad drilling
7
Q314 Operations Update
First Sales Activity
YTD D&C by Business Unit
(1)
Gross operated well count
(2)
Two-stream
(3)
Excludes Tubular oil and gas equipment, prepaid drilling costs and other
(1)
Total $429 MM
(3)
West Division
East Division
Williston
$53
PRB $129
GGR
$32
SJ $4
MCW
$40
MCE $81
ET $90
8
5
6
4
88
23
Q1'14
Q2'14
Q3'14
9ME'14
MC
ET
Williston
GGR
PRB
SJ
YTD
9
7
3
14
3
9
5
6
9
26
39 |
Q1'14
Q2'14
Q3'14
9ME'14
Production (MMcfe/d)
529
543
530
533
Realized Price ($/Mcfe)
$5.67
$5.34
$5.61
$5.54
Operating Expenses ($/Mcfe)
LOE
$0.95
$1.14
$1.12
$1.07
Production Tax
$0.43
$0.44
$0.45
$0.44
Cash G&A
$0.65
$0.58
$0.60
$0.61
Total
$2.03
$2.16
$2.17
$2.12
Cash Operating Margin ($/Mcfe)
$3.64
$3.18
$3.44
$3.42
Adjusted EBITDA ($MM)
$175
$516
8
Q314 Financial & Operating Metrics
(1)
Including realized derivatives
(2)
(3)
Cash operating margin is a non-GAAP financial measure. A description of cash
operating margin is included at the end of this presentation and the calculation of the measure is provided
above
(4)
Adjusted EBITDA is a non-GAAP financial measure. A reconciliation to its nearest
GAAP financial measure is included at the end of this presentation (2)
(3)
(4)
(1)
Income Statement G&A excluding stock-based G&A compensation expenses of $0.21,
$0.19 and $0.24 per Mcfe for the three months ended March 31, June 30 and September 30, 2014,
respectively, and $0.21 per Mcfe for the nine months ended September 30, 2014
|
Q1'14
Q2'14
Q3'14
9ME'14
Cash Flow From Operations
$103
$157
$103
$363
Divestiture Proceeds
$6
$48
$61
$114
Total
$109
$205
$164
$477
Cash Capital Expenditures:
Drilling and Completion
$131
$199
$121
$452
LGG, Facility & Other
$7
$6
$11
$23
Capitalized Cash Interest & Internal Costs
$131
$20
$109
$260
Total
$269
$226
$241
$736
Free Cash Flow before Financing Activities
($160)
($20)
($78)
($258)
Net Debt
$3,815
Liquidity
$433
9
Q314 Financial Position & Liquidity
(1)
($MM)
(2)
Note: Totals may not sum due to independent rounding
(3)
(1)
Includes Tubular oil and gas equipment, prepaid drilling costs and other (2) Reflects net cash provided by operating activities plus net cash
used in investing activities
(3)
Long-term debt less cash and cash equivalents |
As of November
12, 2014 (1)
Volumes are rounded
(2)
2015 includes 20,000 MMBtu/d of Cal 15 collars and 10,000 MMBtu/d of Q115
collars (3)
2016 includes 30,000 MMBtu/d of natural gas collars to the extent our counterparty elects to
exercise their collar options Note: 2014 includes balance of the year only
Year
Bbls/d
(1)
Swap Price
2014
15,000
$90.62
2015
3,500
$90.91
Year
Bbls/d
(1)
Swap Price
2014
7,500
$35.42
2015
750
$37.07
Year
MMBtu/d
(1)
Wtd Avg
Floor
2014
306,000
$4.15
2015
(2)
192,000
$4.05
2016
(3)
161,000
$4.04
2017
40,000
$3.92
NGL Swaps
Oil Swaps
Natural Gas Swaps & Collars
Current Hedge Position
10 |
11
Non-GAAP Disclosures
Cash operating margin, EBITDA, Adjusted EBITDA and Covenant Adjusted EBITDA are non-GAAP
financial measures. We believe that the presentation of these non-GAAP financial
measures will provide useful information to investors in assessing our financial condition and results of operations.
Cash operating margin represents our average realized sales price per Mcfe, including the
effect of realized derivatives, less (i) lease operating expenses per Mcfe, (ii)
production and ad valorem taxes per Mcfe and (iii) general and administrative expenses per Mcfe, excluding stock based compensation
expenses. The per unit components of cash operating margin are determined by dividing
the applicable component by our total production on a natural gas equivalent basis. We
believe that cash operating margin is an important measure that can facilitate comparisons of our performance between periods
and to the performance of our peer companies. EBITDA is
defined as net income (loss) before interest expense, income tax expense (benefit), depreciation and amortization. Adjusted EBITDA represents
EBITDA adjusted as applicable in the relevant period for select items specified in the credit
agreement governing our revolving credit facility, including unrealized hedging losses
(gains), non-cash stock compensation expenses, management and similar fees paid to our sponsors, costs associated with the
preparation and implementation of certain public company compliance obligations, losses
(gains) on non-ordinary course asset dispositions, ceiling test charges and certain
unusual and non-recurring charges. We define Covenant Adjusted EBITDA as total Adjusted EBITDA less the Adjusted EBITDA
attributable to any assets or businesses disposed of during the relevant period. We believe
that the presentation of EBITDA, Adjusted EBITDA and Covenant Adjusted EBITDA is
important to provide management and investors with (i) additional information to evaluate our ability to service and comply
with our debt obligations, adjusting for certain items required or permitted in calculating
covenant compliance under the credit agreement governing our revolving credit facility,
(ii) a supplemental indicator of the operational performance and value of our business, (iii) an additional criterion for evaluating
our performance relative to peer companies and (iv) supplemental information about certain
material non-cash and other items that may not continue at the same level in the
future.
Net income (loss) is the GAAP financial measure most directly comparable to each of EBITDA,
Adjusted EBITDA and Covenant Adjusted EBITDA. Our non- GAAP financial measures
should not be considered as alternatives to the most directly comparable GAAP financial measures. Each of these non-GAAP
financial measures has important limitations as an analytical tool because it excludes some,
but not all, items that affect the most directly comparable GAAP financial measure. You
should not consider these non-GAAP financial measures in isolation or as a substitute for analysis of our results as reported
under GAAP. Because cash operating margin, EBITDA, Adjusted EBITDA and Covenant Adjusted
EBITDA may be defined differently by other companies in our industry, our definitions
of these non-GAAP financial measures may not be comparable to similarly titled measures of other companies, thereby
diminishing their utility. Management
compensates for the limitations of these non-GAAP financial measures as an analytical tool by reviewing the comparable GAAP financial
measures, understanding the difference between the non-GAAP financial measures, on the one
hand, and each of their respective most directly comparable GAAP financial measures, on
the other hand, and incorporating this knowledge into its decision-making processes. We believe that investors
benefit from having access to the same financial measures that our management uses in
evaluating our financial condition and results of operations.
The following table presents reconciliations of EBITDA, Adjusted EBITDA and Covenant Adjusted
EBITDA to net income (loss) for each of the periods indicated. |
12
Q3 2014 Adjusted EBITDA Reconciliation
(1)
(2)
(3)
(4)
Note: Calculated as of 9/30/14 with respect to Samson Resources Corporation and its
consolidated subsidiaries by reference to the applicable terms of the credit agreement governing our
revolving credit facility Three
Months Nine Months
Twelve Months
Ended
Ended
Ended
September 30, 2014
September 30,2014
September 30, 2014
(dollars in thousands)
Net loss
(261,813)
$
(470,657)
$
(1,607,503)
$
Interest expense, net
23,776
65,695
65,695
Benefit for income taxes
(145,267)
(260,862)
(892,577)
122,711
370,244
542,490
$
EBITDA
(260,593)
$
(295,580)
$
(1,891,895)
$
Adjustment for unrealized hedging gains
(68,315)
(45,399)
(18,299)
Adjustment for non-cash stock compensation expense
11,206
34,835
44,244
5,513
16,538
21,788
Adjustment for fees paid for public company compliance
934
1,693
2,215
Loss on sale of other property and equipment
790
1,047
1,155
Provision to reduce carrying value of oil and gas properties
478,467
790,537
2,527,877
Unusual or non-recurring charges described in credit agreement
7,365
11,935
21,304
Adjusted EBITDA
175,367
$
515,606
$
708,389
$
693,876
$
Covenant Adjusted EBITDA
Adjustment for fees paid to co-investors
Depreciation, depletion and amortization
(1)
Includes depreciation, depletion and amortization of oil and gas properties and depreciation
and amortization of other property and equipment and accretion of asset retirement
obligations
(2)
Stock compensation expense recognized in earnings, net of capitalization (3) Quarterly management fee (4) Excludes sold Adjusted EBITDA of approximately
$14.5 MM per the credit agreement governing our revolving credit facility. Covenant Adjusted EBITDA measured on a rolling four-
quarters basis is used to determine our compliance with the financial performance covenant in
the credit agreement governing our revolving credit facility |