As filed with the Securities and Exchange Commission on
July 12, 2007
Registration
No. 333-
UNITED STATES SECURITIES AND
EXCHANGE COMMISSION
Washington, D.C.
20549
Form S-1
REGISTRATION STATEMENT UNDER
THE SECURITIES ACT OF 1933
Approach Resources
Inc.
(Exact name of registrant as
specified in its charter)
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Delaware
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1311
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51-0424817
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(State or other jurisdiction
of
incorporation or organization)
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(Primary Standard Industrial
Classification Code Number)
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(I.R.S. Employer
Identification Number)
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6300 Ridglea Place,
Suite 1107
Fort Worth, Texas
76116
(817) 989-9000
(Address, including zip code,
and telephone number, including
area code, of registrants
principal executive offices)
J. Ross Craft
President and Chief Executive
Officer
6300 Ridglea Place,
Suite 1107
Fort Worth, Texas
76116
(817) 989-9000
(Name, address, including zip
code, and telephone number, including area code, of agent for
service)
Copies to:
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Joe Dannenmaier
Thompson & Knight LLP
1700 Pacific Avenue, Suite 3300
Dallas, Texas 75201
(214) 969-1700
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Gerald S.
Tanenbaum, Esq.
Cahill Gordon & Reindel LLP
80 Pine Street
New York, New York 10005
(212) 701-3000
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As soon as practicable after
this Registration Statement is declared effective.
(Approximate date of
commencement of proposed sale to the public)
If any securities being registered on this form are to be
offered on a delayed or continuous basis pursuant to
Rule 415 under the Securities Act of 1933, as amended (the
Securities Act), check the following
box.
o
If this form is filed to register additional securities for an
offering pursuant to Rule 462(b) under the Securities Act,
check the following box and list the Securities Act registration
statement number of the earlier effective registration statement
for the same offering.
o
If this form is a post-effective amendment filed pursuant to
Rule 462(c) under the Securities Act, check the following
box and list the Securities Act registration statement number of
the earlier effective registration statement for the same
offering.
o
If this form is a post-effective amendment filed pursuant to
Rule 462(d) under the Securities Act, check the following
box and list the Securities Act registration statement number of
the earlier effective registration statement for the same
offering.
o
CALCULATION OF REGISTRATION
FEE
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Proposed
maximum
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aggregate
offering
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Amount of
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Title of each
class of Securities to be registered
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price(1)(2)
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registration
fee
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Common stock, par value $0.01 per
share
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$132,250,000
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$4,061
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(1)
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Estimated solely for the purpose of
calculating the registration fee under Rule 457(o) under
the Securities Act.
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(2)
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Includes common stock issuable upon
exercise of the underwriters option to purchase additional
shares of common stock.
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The registrant hereby amends this registration statement on
such date or dates as may be necessary to delay its effective
date until the registrant shall file a further amendment which
specifically states that this registration statement shall
thereafter become effective in accordance with Section 8(a)
of the Securities Act or until this registration statement shall
become effective on such date as the Commission, acting pursuant
to said Section 8(a), may determine.
The
information in this preliminary prospectus is not complete and
may be changed. We and the selling stockholder may not sell
these securities until the registration statement filed with the
Securities and Exchange Commission is effective. This
preliminary prospectus is not an offer to sell and it is not
soliciting an offer to buy these securities in any jurisdiction
where the offer or sale is not permitted.
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Subject to
completion, dated July 12, 2007
Prospectus
shares
Approach Resources
Inc.
Common stock
Approach Resources Inc. is
selling shares
of common stock, and the selling stockholder identified in this
prospectus is selling an
additional shares.
We will not receive any of the proceeds from the sale of the
shares by the selling stockholder. This is the initial public
offering of our common stock. The estimated initial public
offering price is between $ and
$ per share.
Prior to this offering, there has been no public market for our
common stock. We intend to apply to have our common stock listed
on the NASDAQ Global Market under the symbol AREX.
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Per
share
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Total
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Initial public offering price
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$
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$
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Underwriting discount
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$
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$
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Proceeds to Approach Resources
Inc., before expenses
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$
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$
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Proceeds to selling stockholder,
before expenses(1)
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$
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$
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(1)
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Expenses associated with the
offering, other than underwriting discounts, will be paid by us.
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We and the selling stockholder have granted the underwriters an
option for a period of 30 days to purchase up
to
additional shares of our common stock from us and up
to
additional shares of our common stock from the selling
stockholder on the same terms and conditions set forth above to
cover over-allotments, if any.
Investing in our common stock involves a high degree of risk.
See Risk factors beginning on page 13.
Neither the Securities and Exchange Commission nor any state
securities commission has approved or disapproved of these
securities or passed upon the adequacy or accuracy of this
prospectus. Any representation to the contrary is a criminal
offense.
The underwriters expect to deliver the shares of common stock to
investors
on ,
2007.
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Book running
manager
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Joint lead
manager
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,
2007
Table of
contents
You should rely only on the information contained in this
prospectus. We have not authorized anyone to provide you with
information different from that contained in this prospectus. We
are offering to sell, and seeking offers to buy, shares of our
common stock only in jurisdictions where offers and sales are
permitted. The information contained in this prospectus is
accurate only as of the date of this prospectus, regardless of
the time of delivery of this prospectus or of any sale of our
common stock.
No action is being taken in any jurisdiction outside the United
States to permit a public offering of the common stock or
possession or distribution of this prospectus in that
jurisdiction. Persons who come into possession of this
prospectus in jurisdictions outside the United States are
required to inform themselves about and to observe any
restrictions as to this offering and the distribution of this
prospectus applicable to those jurisdictions.
i
The market data and certain other statistical information used
throughout this prospectus are based on independent industry
publications, governmental publications, reports by market
research firms or other independent sources. Some data are also
based on our good faith estimates. Although we believe these
third-party sources are reliable, we have not independently
verified the information and cannot guarantee its accuracy and
completeness.
The numbers contained in this prospectus relating to our gross
and net leasehold acreage have been rounded to the nearest
thousand acres.
We have filed an application for registration of a service mark
for Approach Resources Inc. Other products, services
and company names mentioned in this prospectus are the service
marks/trademarks of their respective owners.
ii
Prospectus
summary
This summary highlights information contained elsewhere in
this prospectus. Because this section is only a summary, it does
not contain all of the information that may be important to you
or that you should consider before making an investment
decision. For a more complete understanding of this offering, we
encourage you to read this entire prospectus, including the
information contained under the heading Risk
factors. You should read the following summary together
with the more detailed information, pro forma financial
information and combined financial information and the notes
thereto included elsewhere in this prospectus. In this
prospectus, unless the context otherwise requires, the terms
Approach Resources, Approach,
we, us and our refer to the
combined operations of Approach Resources Inc. and Approach
Oil & Gas Inc. and their respective subsidiaries on a
pro forma basis after giving effect to the acquisition by
Approach Resources Inc. from Neo Canyon Exploration, L.P. of the
30% working interest in the Ozona Northeast field that Approach
does not already own, which we refer to as the Neo Canyon
interest.
Approach
Resources Inc.
Overview
We are an independent energy company engaged in the exploration,
development, exploitation, production and acquisition of
unconventional natural gas and oil properties. Our principal
operations are located in the Ozona Northeast field in West
Texas, where we originally acquired approximately
28,000 gross (27,000 net) acres of leasehold interests in
2004. Since that time, through a series of strategic leasehold
acquisitions, we have increased our West Texas acreage to
67,000 gross (52,000 net) acres located in the Ozona
Northeast field and our nearby Cinco Terry project. Our
management team has extensive experience finding and exploiting
unconventional reservoirs, particularly tight gas sands like
Ozona Northeast, by applying advanced completion, fracturing and
drilling techniques. Substantially all of our growth has been
through our own drilling efforts. Since 2004, we have added
approximately 149 Bcfe of proved gas and oil reserves from
unconventional reservoir formations.
At December 31, 2006, all of our proved reserves and
production were located in West Texas and substantially all of
those reserves and production were located in the Ozona
Northeast field. As of such date, we owned working interests in
241 gross (226 net) producing wells with an average net
production of approximately 22 MMcfe/d for the month of
December 2006. At December 31, 2006, our total proved gas
and oil reserves were approximately 149 Bcfe with a reserve
life index of approximately 19 years. Our proved reserves
are 94% gas and 51% proved developed. As the operator of
substantially all of our proved reserves, we have a high degree
of control over capital expenditures and other operating
matters. As of December 31, 2006, we had identified a total
of 795 drilling locations, of which 668 were located in the
Ozona Northeast field and 127 in our Cinco Terry project.
Our growth efforts are focused primarily on finding and
developing natural gas reserves in known tight gas sands and
shale areas onshore in the United States. Since May 2006, we
have acquired leasehold interests covering 74,000 gross
(44,000 net) acres in Western Kentucky and 90,000 gross
(81,000 net) acres in Northern New Mexico. In total we have
assembled leasehold interests of 231,000 gross (177,000
net) acres in our three operating areas West Texas
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(Wolfcamp, Canyon Sands and Ellenburger), Western Kentucky (New
Albany Shale) and Northern New Mexico (Mancos Shale).
The following table sets forth a summary of our estimated proved
reserves and net average production attributable to our
principal areas of operation as of December 31, 2006.
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Estimated proved
reserves
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Proved
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Net average
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Total
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developed
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PV-10(1)
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production
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(Bcfe)
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(Bcfe)
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(millions)
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(MMcfe/d)
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Ozona Northeast
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147.0
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74.9
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$
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175.7
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21.9
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Cinco Terry
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1.8
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0.9
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4.2
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0.3
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Western Kentucky
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Northern New Mexico
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Total
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148.8
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75.8
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$
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179.9
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22.2
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(1)
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PV-10
is a non-GAAP financial measure and generally differs from the
standardized measure of discounted future net cash flows, the
most directly comparable GAAP financial measure, because it does
not include the effects of income taxes on future net revenues.
See Selected historical combined financial
dataReconciliation of non-GAAP financial measures
for our definition of
PV-10
and a
reconciliation of
PV-10
to the
standardized measure of discounted future net cash flows. Our
calculation of
PV-10
set
forth in this table is based on gas and oil and condensate
prices actually received by us on December 31, 2006, held
flat for the life of the reserves. The weighted average price
over the life of the Ozona Northeast reserves was $6.55 per Mcf
of gas and $58.05 per Bbl of oil. The weighted average price
over the life of the Cinco Terry reserves was $5.65 per Mcf of
gas and $58.05 per Bbl of oil.
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The following table sets forth a summary of our net acreage
leasehold and estimated capital budget attributable to our
principal areas of operation as of May 31, 2007, as well as
identified drilling locations as of December 31, 2006. We
currently anticipate drilling 60 wells in 2007, at an
estimated total cost of $44.9 million.
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Identified
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Capital
budget(2)
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Net acreage
leasehold
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drilling
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2007
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2008
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Developed
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Undeveloped
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Total
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locations(1)
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(millions)
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(millions)
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Ozona Northeast
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27,000
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17,000
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44,000
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668
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$
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34.3
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$
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50.5
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Cinco Terry
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1,000
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7,000
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8,000
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127
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2.2
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4.1
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Western Kentucky
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44,000
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44,000
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4.6
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6.6
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Northern New Mexico
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81,000
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81,000
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3.8
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4.5
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Total
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28,000
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149,000
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177,000
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795
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$
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44.9
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$
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65.7
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(1)
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Identified drilling locations
represent total gross locations specifically identified by
management as an estimate of our future multi-year drilling
inventory on existing acreage. Of the total locations shown in
the table, 203 are classified as proved. As of May 31,
2007, we had completed drilling 17 locations shown in the table,
including 15 proved undeveloped locations. Our actual drilling
activities may change depending on gas and oil prices, the
availability of capital, costs, drilling results, regulatory
approvals and other factors. See Risk factorsRisks
related to our business.
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(2)
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An additional $4.4 million and
$800,000 for 2007 and 2008, respectively, budgeted for lease
acquisition, geophysical and geologic costs is not reflected
here.
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2
Areas of
operation
West
Texas
Ozona
Northeast field (Canyon Sands)
The Ozona Northeast field, in Crockett and Schleicher counties,
Texas, is our largest operating area on the basis of proved
reserves and production. The Canyon Sands of the Val Verde Basin
in West Texas are located in a prolific tight gas reservoir with
more than 11,800 total productive wells and cumulative
historical production of more than 3.8 Tcfe over more than
50 years. In 2004, we began operations in the field through
a farmout arrangement and have increased our total acreage
position to 45,000 gross (44,000 net) acres. Beginning with
our first well in February 2004, through December 31, 2006,
we have drilled 237 successful wells out of 250 total wells
drilled, which is a 95% success rate. As of December 31,
2006, we had 237 producing wells with proved reserves of
147 Bcfe. From 2004 through 2006, as a result of our own
drilling efforts, we achieved a compound annual production
growth rate of over 100%. We have identified 668 additional
drilling locations in the field, and we estimate that completed
costs per location currently are approximately $770,000, based
on current markets for drilling services and equipment.
Additionally, we own and operate 65 miles of gas gathering
lines in the area that transport our gas to several regional
pipeline systems.
Cinco Terry
project (Wolfcamp, Canyon Sands and Ellenburger)
Since late 2005, we have leased and acquired options to lease
22,000 gross (8,000 net) acres five miles west of the Ozona
Northeast field to evaluate the Wolfcamp, Canyon and Ellenburger
formations. As of May 31, 2007, we had drilled and
completed three Canyon wells and one Ellenburger well at a total
cost of $5.9 million gross and $3.0 million net. As of
December 31, 2006, we had proved reserves in the Cinco
Terry project of 1.8 Bcfe. Wolfcamp wells in this area have
demonstrated significant commercial production, and we are
evaluating the formation for possible horizontal completions.
Based upon data collected in the process of drilling the Canyon
and Ellenburger wells, we believe we could achieve additional
success in the shallower Wolfcamp formation. We own and operate
seven miles of gas gathering lines in the area that transport
our gas to several regional pipeline systems.
Western
Kentucky
Boomerang
prospect (New Albany Shale)
Our Boomerang prospect is a 74,000 gross (44,000 net)
acre New Albany Shale play located in Western Kentucky in
an under-explored area of the Illinois Basin. We believe the
attributes of the New Albany Shale in the Boomerang prospect
make it a promising resource play, particularly with the
introduction of horizontal drilling technology. In the first
quarter of 2007, we drilled three vertical test wells. We have
contracted to have core samples from these three wells analyzed.
We expect to begin the horizontal completion of these three test
wells in the third quarter of 2007. After evaluating the results
of our initial drilling and completion activities, we will
determine our development program in this prospect.
3
Northern New
Mexico
El Vado East
prospect (Mancos Shale)
Our El Vado East prospect is a 90,000 gross (81,000 net)
acre Mancos Shale play located in the Chama Basin in
Northern New Mexico in close proximity to several highly
productive fields, including the West and East Puerto Chiquito
fields and the Boulder field, which collectively have produced
in excess of 18 MMBoe of oil. Although our primary
objective in the El Vado East prospect is the Mancos Shale,
finding commercial production in the Dakota, Morrison, Todilto
and Entrada formations is a secondary objective. We expect that
in the third quarter of 2007 we will spud the first of four
vertical test wells to be identified and drilled in the El Vado
East prospect. Depending on the initial results of these wells,
we may elect to shoot
3-D
seismic
over a portion of this prospect at locations which have yet to
be identified.
Strategy
Our strategy is to increase stockholder value by profitably
growing our reserves, production, cash flow and earnings using a
balanced program of (1) developing existing properties,
(2) exploring and exploiting undeveloped properties,
(3) completing strategic acquisitions and
(4) maintaining financial flexibility. The following are
key elements of our strategy:
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Continue to develop our existing West Texas properties.
We intend to develop further the significant remaining
potential of our West Texas properties, where we have identified
795 drilling locations. From 2004 through 2006, we drilled
257 wells in our West Texas fields, making us one of the top ten
most active drillers in West Texas and the second most active
driller in the Canyon Sands during that time period.
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Pursue unconventional gas and oil
opportunities.
With our Boomerang and El Vado East
prospects, we have 164,000 gross acres of unexplored shale
gas and oil inventory to explore and produce. We seek to add
proved reserves and production from these properties through the
application of advanced technologies, including horizontal
drilling and advanced completion techniques.
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Acquire strategic assets.
We continually review
opportunities to acquire producing properties, undeveloped
acreage and drilling prospects. We focus particularly on
opportunities where we believe our reservoir management and
operational expertise in unconventional gas and oil properties
will enhance value and performance. We remain focused on
unconventional resource opportunities, but also look at
conventional opportunities based on individual project economics.
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Operate our properties as a low cost producer.
We
strive to minimize our operating costs by concentrating our
assets within geographic areas where we can consolidate
operating control and thus create operating efficiencies. We are
the operator of substantially all of our producing properties
and plan to continue to operate substantially all of our
producing properties in the future. Operating control allows us
to better manage timing and risk as well as the cost of
exploration and development, drilling and ongoing operations.
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4
Competitive
strengths
We believe our historical success is, and future performance
will be, directly related to the following combination of
strengths that enable us to implement our strategy:
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Experienced executive and technical team with significant
employee ownership
. The members of our executive and
technical team (including our Chief Executive Officer) have an
average of more than 26 years of experience in the oil and
gas industry and significant experience in building and managing
independent oil and gas companies. The majority of our executive
and technical team have spent their entire careers developing
unconventional gas and oil properties. Our team has a proven
record of analyzing complex structural and stratigraphic
formations using
3-D
seismic
and geological techniques, producing and optimizing gas
reservoirs and drilling and completing unconventional gas
reservoirs. Our management team and employees will own
approximately % of our common stock
after this offering, aligning their objectives with those of our
stockholders.
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Low risk, multi-year drilling inventory.
We have
identified 795 drillable, low to moderate risk locations on our
West Texas properties, providing us with approximately
10 years of drilling inventory at our current drilling
rate. Our technical teams ability to locate and execute on
repeatable low-risk drilling opportunities in our large and
productive West Texas acreage holdings has helped us to achieve
a drilling success rate of 94% since our inception.
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Stable producing asset base.
We own an operated
asset base comprising of long-lived reserves. Approximately 94%
of our reserves are gas, and all of our proved reserves are
located in West Texas. These properties should produce stable
cash flows to fund our development, exploitation and exploration
opportunities.
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Large acreage positions.
We are a significant
acreage holder in each of our three primary operating areas with
an aggregate leasehold position of 231,000 gross (177,000
net) acres. We believe we have assembled a portfolio of
properties, both in prolific producing gas and oil fields and in
under-explored reservoirs, that would be difficult to replicate.
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Operated asset base.
We operate substantially all of
our estimated reserves. By maintaining operating control, we are
able to more effectively control our expenses, capital
allocation and the timing and method of exploitation and
development of our properties.
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Low cost structure.
Our reserve potential in our
operating areas, our technical expertise and our high rate of
drilling success have allowed us to achieve relatively low
finding and development costs. Since our inception and through
December 31, 2006, we have invested approximately
$200 million to drill and complete 241 wells in our
West Texas operating areas, achieving an average finding and
development cost of $1.38 per Mcfe. See
BusinessHistorical finding and development
costs. During the same time period, our lease operating
costs, including production taxes, averaged $0.91 per Mcfe.
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Financial flexibility.
Upon the completion of this
offering, we expect to have approximately
$ million in cash, no
long-term debt and at least
$ million available for
borrowings under our revolving credit facility, providing us
with significant financial flexibility to pursue our business
strategy.
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Control of gathering infrastructure and gas
marketing.
We own and operate approximately
72 miles of gas gathering lines in West Texas. Owning and
operating this infrastructure allows
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us to maintain greater control of our gathering pressures and to
minimize down time associated with the system.
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Risk
factors
There are a number of risks that could limit our competitive
strengths or ability to successfully implement our business
strategies, including the speculative nature of gas and oil
exploration, competition, volatile gas and oil prices and the
other risks described in this prospectus. In addition, while we
may implement our business strategies, the benefits derived from
such implementation may be mitigated, in whole or in part, if we
suffer from one or more of the risks described in Risk
factors.
Our
structure
Approach Resources Inc. was formed as a Delaware corporation in
September 2002. Our operations are currently conducted by two
separate entities under common control, Approach Resources Inc.
and Approach Oil & Gas Inc. Pursuant to a contribution
agreement, the operations of Approach Oil & Gas Inc.
will be combined under Approach Resources Inc., and we also will
acquire the Neo Canyon interest immediately prior to the closing
of this offering. For more information about our restructuring
and our acquisition of the Neo Canyon interest, please read
Certain relationships and related party
transactionsThe contribution agreement.
Our executive
offices
Our principal executive offices are located at 6300 Ridglea
Place, Suite 1107, Fort Worth, Texas 76116. Our
telephone number is
(817) 989-9000.
6
The
offering
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Common stock offered by us
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shares
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Common stock offered by the selling stockholder
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shares
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Common stock to be outstanding after this offering
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shares
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Use of proceeds
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We expect to receive net proceeds from the sale of shares
offered by us, after deducting estimated offering expenses and
underwriting discounts, of approximately
$ million, based on an
assumed offering price of $ per
share (the mid-point of the price range set forth on the front
cover of this prospectus). We intend to use the net proceeds of
this offering to repay approximately
$ million outstanding under
our revolving credit facility, to
repurchase shares of our
common stock held by Neo Canyon Exploration, L.P. at a purchase
price of
$ million
and the remainder for general corporate purposes, including
exploration and development activities, gas and oil reserve and
leasehold acquisitions in the ordinary course of business and
for working capital. We will not receive any proceeds from the
sale of shares of our common stock by the selling stockholder.
See Use of proceeds.
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Dividend policy
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We do not anticipate paying any cash dividends on our common
stock. See Dividend policy.
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Risk factors
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For a discussion of factors you should consider in making an
investment, see Risk factors.
|
|
Proposed NASDAQ Global Market symbol
|
|
AREX
|
|
Other information about this prospectus
|
|
Unless specifically stated otherwise, the information in this
prospectus:
|
|
|
|
is adjusted to reflect
a
for
stock split of our shares of common stock to be effected in the
form of a stock dividend concurrent with the consummation of
this offering;
|
|
|
|
assumes no exercise of the underwriters option
to purchase additional shares of our common stock to cover
over-allotments, if any; and
|
|
|
|
assumes an initial public offering price of
$ , which is the mid-point of the
range set forth on the front cover of this prospectus.
|
7
Summary combined
historical and combined
pro forma financial data
The following table sets forth our summary historical combined
and combined pro forma financial and operating data as of the
dates and for the periods shown. Our operations are currently
conducted by two separate operating entities under common
control, Approach Resources Inc. and Approach Oil &
Gas Inc. Pursuant to a contribution agreement, the operations of
Approach Oil & Gas Inc. will be combined under
Approach Resources Inc., and we also will acquire the Neo Canyon
interest immediately prior to the closing of this offering. The
amounts for each historical annual period presented below were
derived from the audited combined financial statements of
Approach Resources Inc. and Approach Oil & Gas Inc.
included in this prospectus. The combined pro forma financial
information gives effect to our acquisition of the Neo Canyon
interest. The combined pro forma balance sheet assumes that the
acquisition of the Neo Canyon interest occurred as of
March 31, 2007, and the combined pro forma statements of
operations for the year ended December 31, 2006 and for the
three months ended March 31, 2007 assume that the
acquisition of the Neo Canyon interest occurred on the first day
of the respective period. The combined pro forma balance sheet
and the combined pro forma statement of operations were derived
by adjusting the historical combined financial statements of
Approach Resources Inc. and Approach Oil & Gas Inc.
These adjustments are based on currently available information
and certain estimates and assumptions, and, therefore, the
actual effects of the acquisition of the Neo Canyon interest may
differ from the effects reflected in the combined pro forma
financial statements. However, management believes that the
assumptions provide a reasonable basis for presenting the
significant effects of this transaction as contemplated and that
the pro forma adjustments give appropriate effect to those
assumptions. The pro forma financial information is not
necessarily indicative of the financial condition or results of
operations of Approach Resources Inc. had the contribution and
the acquisitions taken place on the assumed dates and should not
be viewed as indicative of operations in the future. The
following information should be read in conjunction with
Capitalization, Managements discussion
and analysis of financial condition and results of
operations and the historical combined and combined pro
forma financial statements included in this prospectus.
8
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro
forma
|
|
|
|
|
|
|
|
|
|
|
|
|
Three months
|
|
|
|
|
|
Three months
|
|
|
|
|
|
|
|
|
|
|
|
|
ended
|
|
|
Year ended
|
|
|
ended
|
|
(in thousands,
except shares and per
|
|
Year ended
December 31,
|
|
|
March 31,
|
|
|
December 31,
|
|
|
March 31,
|
|
share
data)
|
|
2004
|
|
|
2005
|
|
|
2006
|
|
|
2006
|
|
|
2007
|
|
|
2006
|
|
|
2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(unaudited
|
)
|
|
|
(unaudited
|
)
|
|
|
(unaudited
|
)
|
|
|
(unaudited
|
)
|
Statement of operations
data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil and gas sales
|
|
$
|
5,682
|
|
|
$
|
40,339
|
|
|
$
|
52,894
|
|
|
$
|
15,680
|
|
|
$
|
11,547
|
|
|
$
|
72,452
|
|
|
$
|
15,349
|
|
Overhead and services income
|
|
|
131
|
|
|
|
408
|
|
|
|
514
|
|
|
|
122
|
|
|
|
133
|
|
|
|
175
|
|
|
|
32
|
|
|
|
|
|
|
|
Total revenues
|
|
|
5,813
|
|
|
|
40,747
|
|
|
|
53,408
|
|
|
|
15,802
|
|
|
|
11,680
|
|
|
|
72,627
|
|
|
|
15,381
|
|
Expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating expense
|
|
|
179
|
|
|
|
2,910
|
|
|
|
3,889
|
|
|
|
973
|
|
|
|
979
|
|
|
|
5,757
|
|
|
|
1,416
|
|
Severance and production taxes
|
|
|
407
|
|
|
|
1,975
|
|
|
|
1,736
|
|
|
|
380
|
|
|
|
375
|
|
|
|
2,452
|
|
|
|
526
|
|
Exploration
|
|
|
2,396
|
|
|
|
733
|
|
|
|
1,640
|
|
|
|
196
|
|
|
|
623
|
|
|
|
1,640
|
|
|
|
623
|
|
Impairment of non-producing
properties
|
|
|
|
|
|
|
|
|
|
|
558
|
|
|
|
|
|
|
|
|
|
|
|
558
|
|
|
|
|
|
General and administrative
|
|
|
2,074
|
|
|
|
3,067
|
|
|
|
2,930
|
|
|
|
750
|
|
|
|
1,646
|
|
|
|
2,930
|
|
|
|
1,646
|
|
Accretion of discount on asset
retirement obligations
|
|
|
1
|
|
|
|
5
|
|
|
|
10
|
|
|
|
|
|
|
|
3
|
|
|
|
14
|
|
|
|
3
|
|
Depletion, depreciation and
amortization
|
|
|
1,223
|
|
|
|
8,006
|
|
|
|
14,541
|
|
|
|
3,281
|
|
|
|
3,088
|
|
|
|
22,055
|
|
|
|
4,737
|
|
|
|
|
|
|
|
Total expenses
|
|
|
6,280
|
|
|
|
16,696
|
|
|
|
25,304
|
|
|
|
5,580
|
|
|
|
6,714
|
|
|
|
35,406
|
|
|
|
8,951
|
|
|
|
|
|
|
|
Operating income (loss)
|
|
|
(467
|
)
|
|
|
24,051
|
|
|
|
28,104
|
|
|
|
10,222
|
|
|
|
4,966
|
|
|
|
37,221
|
|
|
|
6,430
|
|
Other:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income (expense), net
|
|
|
201
|
|
|
|
(802
|
)
|
|
|
(3,814
|
)
|
|
|
(725
|
)
|
|
|
(956
|
)
|
|
|
(3,814
|
)
|
|
|
(956
|
)
|
Change in fair value of commodity
derivatives
|
|
|
|
|
|
|
(4,163
|
)
|
|
|
8,668
|
|
|
|
6,192
|
|
|
|
(4,626
|
)
|
|
|
8,668
|
|
|
|
(4,626
|
)
|
|
|
|
|
|
|
Income (loss) before provision
(benefit) for income taxes
|
|
|
(266
|
)
|
|
|
19,086
|
|
|
|
32,958
|
|
|
|
15,689
|
|
|
|
(616
|
)
|
|
|
42,075
|
|
|
|
848
|
|
Provision (benefit) for income taxes
|
|
|
|
|
|
|
7,028
|
|
|
|
11,756
|
|
|
|
5,280
|
|
|
|
(35
|
)
|
|
|
15,129
|
|
|
|
473
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$
|
(266
|
)
|
|
$
|
12,058
|
|
|
$
|
21,202
|
|
|
$
|
10,409
|
|
|
$
|
(581
|
)
|
|
$
|
26,946
|
|
|
$
|
375
|
|
|
|
|
|
|
|
Earnings (loss) per share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
(0.14
|
)
|
|
$
|
4.03
|
|
|
$
|
7.04
|
|
|
$
|
3.49
|
|
|
$
|
(0.19
|
)
|
|
$
|
5.78
|
|
|
$
|
0.08
|
|
Diluted
|
|
$
|
(0.14
|
)
|
|
$
|
4.03
|
|
|
$
|
6.84
|
|
|
$
|
3.39
|
|
|
$
|
(0.19
|
)
|
|
$
|
5.67
|
|
|
$
|
0.08
|
|
Weighted average shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
1,928,225
|
|
|
|
2,988,986
|
|
|
|
3,012,414
|
|
|
|
2,985,000
|
|
|
|
2,987,411
|
|
|
|
4,663,022
|
|
|
|
4,580,211
|
|
Diluted
|
|
|
1,928,225
|
|
|
|
2,988,986
|
|
|
|
3,101,180
|
|
|
|
3,069,945
|
|
|
|
2,987,411
|
|
|
|
4,751,788
|
|
|
|
4,693,441
|
|
Statement of cash flow
data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided (used) by:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating activities
|
|
$
|
4,527
|
|
|
$
|
40,304
|
|
|
$
|
34,110
|
|
|
$
|
12,616
|
|
|
$
|
5,687
|
|
|
|
|
|
|
|
|
|
Investing activities
|
|
|
(26,859
|
)
|
|
|
(71,939
|
)
|
|
|
(59,189
|
)
|
|
|
(24,578
|
)
|
|
|
(9,717
|
)
|
|
|
|
|
|
|
|
|
Financing activities
|
|
|
22,474
|
|
|
|
32,199
|
|
|
|
26,771
|
|
|
|
9,918
|
|
|
|
4,493
|
|
|
|
|
|
|
|
|
|
Other financial data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDAX(1)
|
|
|
3,152
|
|
|
|
32,791
|
|
|
|
44,877
|
|
|
|
13,699
|
|
|
|
8,677
|
|
|
|
61,508
|
|
|
|
11,790
|
|
Capital expenditures
|
|
|
25,313
|
|
|
|
73,485
|
|
|
|
59,189
|
|
|
|
24,578
|
|
|
|
9,717
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
|
See Selected historical
combined financial dataReconciliation of non-GAAP
financial measures for a reconciliation of our net income
(loss) to EBITDAX.
|
9
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro
forma
|
|
as
adjusted(1)
|
|
|
|
|
|
|
|
|
|
|
|
|
As of
|
|
As of
|
|
|
As of
December 31,
|
|
As of
March 31,
|
|
March 31,
|
|
March 31,
|
(in
thousands)
|
|
2004
|
|
2005
|
|
2006
|
|
2006
|
|
2007
|
|
2007
|
|
2007
|
|
|
|
|
|
|
|
|
|
(unaudited)
|
|
(unaudited)
|
|
(unaudited)
|
|
(unaudited)
|
|
Balance sheet data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$
|
2,656
|
|
$
|
3,219
|
|
$
|
4,911
|
|
$
|
1,175
|
|
$
|
5,374
|
|
$
|
5,374
|
|
|
|
Other current assets
|
|
|
6,458
|
|
|
16,305
|
|
|
13,200
|
|
|
16,660
|
|
|
6,776
|
|
|
6,776
|
|
|
|
Property and equipment, net,
successful efforts method
|
|
|
24,223
|
|
|
88,803
|
|
|
132,112
|
|
|
109,904
|
|
|
138,123
|
|
|
207,586
|
|
|
|
Other assets
|
|
|
1,565
|
|
|
89
|
|
|
86
|
|
|
101
|
|
|
119
|
|
|
119
|
|
|
|
|
|
|
|
|
|
Total assets
|
|
$
|
34,902
|
|
$
|
108,416
|
|
$
|
150,309
|
|
$
|
127,840
|
|
$
|
150,392
|
|
$
|
219,855
|
|
|
|
|
|
|
|
|
|
Current liabilities
|
|
$
|
9,827
|
|
$
|
32,746
|
|
$
|
15,421
|
|
$
|
26,811
|
|
$
|
11,564
|
|
$
|
11,564
|
|
|
|
Long-term debt
|
|
|
100
|
|
|
29,425
|
|
|
47,619
|
|
|
40,660
|
|
|
52,169
|
|
|
52,169
|
|
|
|
Other long-term liabilities
|
|
|
99
|
|
|
6,555
|
|
|
17,697
|
|
|
11,562
|
|
|
17,669
|
|
|
17,732
|
|
|
|
Stockholders equity
|
|
|
24,876
|
|
|
39,690
|
|
|
69,572
|
|
|
48,807
|
|
|
68,990
|
|
|
138,390
|
|
|
|
|
|
|
|
|
|
Total liabilities and
stockholders equity
|
|
$
|
34,902
|
|
$
|
108,416
|
|
$
|
150,309
|
|
$
|
127,840
|
|
$
|
150,392
|
|
$
|
219,855
|
|
|
|
|
|
|
|
|
(1)
|
|
As adjusted for the consummation of
the transactions described under Certain relationships and
related party transactionsThe contribution
agreement, our
for
common stock split and the sale
of shares
of common stock in this offering at an assumed initial public
offering price of $ per share,
after deducting underwriting discounts and estimated offering
expenses payable by us and the application of the estimated net
proceeds from this offering as set forth under Use of
proceeds.
|
10
Summary oil and
gas data
Operating
data
The following table presents certain information with respect to
the combined historical operating data for the years ended
December 31, 2004, 2005 and 2006 and for the three months
ended March 31, 2007 and combined pro forma operating data
for the year ended December 31, 2006 and the three months
ended March 31, 2007, after giving effect to our
acquisition of the Neo Canyon interest:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro
forma
|
|
|
|
|
|
|
|
|
Three
|
|
|
|
Three
|
|
|
|
|
|
|
|
|
months
|
|
|
|
months
|
|
|
|
|
|
|
|
|
ended
|
|
Year ended
|
|
ended
|
|
|
Year ended
December 31,
|
|
March 31,
|
|
December 31,
|
|
March 31,
|
|
|
2004
|
|
2005
|
|
2006
|
|
2007
|
|
2006
|
|
2007
|
|
|
Gross wells
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Drilled
|
|
|
54
|
|
|
120
|
|
|
83
|
|
|
9
|
|
|
83
|
|
|
9
|
Completed
|
|
|
46
|
|
|
115
|
|
|
81
|
|
|
8
|
|
|
81
|
|
|
8
|
Net wells
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Drilled
|
|
|
34.9
|
|
|
77.2
|
|
|
55.1
|
|
|
6.3
|
|
|
79.6
|
|
|
9.0
|
Completed
|
|
|
29.6
|
|
|
74.8
|
|
|
53.5
|
|
|
5.6
|
|
|
77.3
|
|
|
8.0
|
Net production data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net volume (MMcfe)
|
|
|
908
|
|
|
5,012
|
|
|
6,744
|
|
|
1,357
|
|
|
9,580
|
|
|
1,910
|
Average daily volume (MMcfe/d)
|
|
|
4
|
|
|
14
|
|
|
18
|
|
|
15
|
|
|
26
|
|
|
21
|
Average sales price (per
Mcfe)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Average sales price
(without hedge)
|
|
$
|
6.26
|
|
$
|
8.63
|
|
$
|
6.92
|
|
$
|
6.92
|
|
$
|
6.91
|
|
$
|
6.91
|
Average sales price
(with hedge)
|
|
|
6.26
|
|
|
8.05
|
|
|
7.84
|
|
|
8.51
|
|
|
7.56
|
|
|
8.04
|
Expenses (per Mcfe)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating
|
|
$
|
0.20
|
|
$
|
0.58
|
|
$
|
0.58
|
|
$
|
0.72
|
|
$
|
0.60
|
|
$
|
0.74
|
Production taxes
|
|
|
0.45
|
|
|
0.39
|
|
|
0.26
|
|
|
0.28
|
|
|
0.26
|
|
|
0.28
|
General and administrative
|
|
|
2.28
|
|
|
0.61
|
|
|
0.43
|
|
|
1.21
|
|
|
0.31
|
|
|
0.86
|
Depreciation, depletion and
amortization
|
|
|
1.35
|
|
|
1.60
|
|
|
2.16
|
|
|
2.26
|
|
|
2.30
|
|
|
2.47
|
|
|
11
Estimated reserve
data
The estimates in the table below of proved reserves as of
December 31, 2004 and 2005 are based on reserve reports
prepared by our engineering staff and Cawley,
Gillespie & Associates, Inc. The estimates as of
December 31, 2006 are based on reserve reports prepared by
our engineering staff and DeGolyer & MacNaughton.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro
forma(1)
|
|
|
December 31,
|
|
December 31,
|
|
|
2004
|
|
2005
|
|
2006
|
|
2006
|
|
|
Estimated proved
reserves
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas (Bcf)
|
|
|
57.7
|
|
|
102.4
|
|
|
98.7
|
|
|
139.8
|
Oil (MMBbls)
|
|
|
0.4
|
|
|
1.1
|
|
|
1.1
|
|
|
1.5
|
|
|
|
|
|
|
Total proved reserves (Bcfe)
|
|
|
59.8
|
|
|
108.9
|
|
|
105.4
|
|
|
148.8
|
Total proved developed reserves
(Bcfe)
|
|
|
17.6
|
|
|
49.8
|
|
|
53.1
|
|
|
75.8
|
PV-10
value (millions)(2)
|
|
|
|
|
|
|
|
|
|
|
|
|
Proved developed reserves
|
|
$
|
44.1
|
|
$
|
151.9
|
|
$
|
112.8
|
|
$
|
158.3
|
Proved undeveloped reserves
|
|
|
56.6
|
|
|
97.4
|
|
|
15.6
|
|
|
21.6
|
|
|
|
|
|
|
Total
PV-10
|
|
$
|
100.7
|
|
$
|
249.3
|
|
$
|
128.4
|
|
$
|
179.9
|
|
|
|
|
|
(1)
|
|
Gives effect to our acquisition of
the Neo Canyon interest.
|
|
(2)
|
|
PV-10
is a non-GAAP financial measure and generally differs from the
standardized measure of discounted future net cash flows, the
most directly comparable GAAP financial measure, because it does
not include the effects of income taxes on future net revenues.
See Selected historical combined financial
dataReconciliation of non-GAAP financial measures
for our definition of
PV-10
and a
reconciliation of
PV-10
to the
standardized measure of discounted future net cash flows. Our
calculation of
PV-10
set
forth in this table is based on gas and oil and condensate
prices actually received by us on December 31, 2006, held
flat for the life of the reserves. The weighted average price
over the life of the Ozona Northeast reserves was $6.55 per Mcf
of gas and $58.05 per Bbl of oil. The weighted average price
over the life of the Cinco Terry reserves was $5.65 per Mcf of
gas and $58.05 per Bbl of oil.
|
12
Risk
factors
You should carefully consider the risk factors set forth
below as well as the other information contained in this
prospectus before investing in our common stock. Any of the
following risks could materially and adversely affect our
business, financial condition or results of operations. In such
a case, you may lose all or part of your investment. The risks
described below are not the only risks facing us. Additional
risks and uncertainties not currently known to us or those we
currently view to be immaterial may also materially adversely
affect our business, financial condition or results of
operations.
Risks related to
our business
Gas and oil
prices are volatile, and a decline in gas or oil prices could
significantly affect our business, financial condition or
results of operations and our ability to meet our capital
expenditure requirements and financial
commitments.
Our revenues, profitability and cash flow depend substantially
upon the prices and demand for gas and oil. The markets for
these commodities are volatile, and even relatively modest drops
in prices can affect significantly our financial results and
impede our growth. Prices for gas and oil fluctuate widely in
response to relatively minor changes in the supply and demand
for gas and oil, market uncertainty and a variety of additional
factors beyond our control, such as:
|
|
|
domestic and foreign supply of gas and oil;
|
|
|
price and quantity of foreign imports;
|
|
|
commodity processing, gathering and transportation availability
and the availability of refining capacity;
|
|
|
domestic and foreign governmental regulations;
|
|
|
political conditions in or affecting other gas producing and oil
producing countries, including the current conflicts in the
Middle East and conditions in South America and Russia;
|
|
|
the ability of the members of the Organization of Petroleum
Exporting Countries to agree to and maintain oil price and
production controls;
|
|
|
weather conditions, including unseasonably warm winter weather;
|
|
|
technological advances affecting gas and oil consumption;
|
|
|
overall United States and global economic conditions; and
|
|
|
price and availability of alternative fuels.
|
Further, gas prices and oil prices do not necessarily fluctuate
in direct relationship to each other. Because more than 94% of
our estimated proved reserves as of December 31, 2006 were
gas reserves, our financial results are more sensitive to
movements in gas prices. In the past, the price of gas has been
extremely volatile, and we expect this volatility to continue.
For example, during the year ended December 31, 2006, the
NYMEX gas spot price ranged from a high of $9.90 per MMBtu to a
low of $3.66 per MMBtu. The NYMEX gas spot price at
December 31, 2006 was $5.50 per MMBtu. At May 1, 2007,
the NYMEX gas spot price was $7.64 per MMBtu.
13
The results of higher investment in the exploration for and
production of gas and other factors may cause the price of gas
to drop. Lower gas and oil prices may not only cause our
revenues to decrease but also may reduce the amount of gas and
oil that we can produce economically. Substantial decreases in
gas and oil prices would render uneconomic some or all of our
drilling locations. This may result in our having to make
substantial downward adjustments to our estimated proved
reserves and could have a material adverse effect on our
financial condition, results of operations and cash flow.
Drilling and
exploring for, and producing, gas and oil are high risk
activities with many uncertainties that could adversely affect
our business, financial condition or results of
operations.
Drilling and exploration are the main methods we use to replace
our reserves. However, drilling and exploration operations may
not result in any increases in reserves for various reasons.
Exploration activities involve numerous risks, including the
risk that no commercially productive gas or oil reservoirs will
be discovered. In addition, the future cost and timing of
drilling, completing and producing wells is often uncertain.
Furthermore, drilling operations may be curtailed, delayed or
canceled as a result of a variety of factors, including:
|
|
|
lack of acceptable prospective acreage;
|
|
|
inadequate capital resources;
|
|
|
unexpected drilling conditions, pressure or irregularities in
formations, equipment failures or accidents;
|
|
|
adverse weather conditions, including tornados;
|
|
|
unavailability or high cost of drilling rigs, equipment or labor;
|
|
|
reductions in gas and oil prices;
|
|
|
limitations in the market for gas and oil;
|
|
|
surface access restrictions;
|
|
|
title problems;
|
|
|
compliance with governmental regulations; and
|
|
|
mechanical difficulties.
|
Our decisions to purchase, explore, develop and exploit
prospects or properties depend in part on data obtained through
geophysical and geological analyses, production data and
engineering studies, the results of which are often uncertain.
Even when used and properly interpreted,
3-D
seismic
data and visualization techniques only assist geoscientists and
geologists in identifying subsurface structures and hydrocarbon
indicators. They do not allow the interpreter to know
conclusively if hydrocarbons are present or producible
economically. In addition, the use of
3-D seismic
and other advanced technologies require greater predrilling
expenditures than traditional drilling strategies.
In addition, higher gas and oil prices generally increase the
demand for drilling rigs, equipment and crews and can lead to
shortages of, and increasing costs for, such drilling equipment,
services and personnel. Such shortages could restrict our
ability to drill the wells and conduct the operations that we
currently have planned. Any delay in the drilling of new wells
or
14
significant increase in drilling costs could adversely affect
our ability to increase our reserves and production and reduce
our revenues.
Currently, the
vast majority of our producing properties are located in two
counties in Texas, and our proved reserves are primarily
attributable to one field in that area, making us vulnerable to
risks associated with having our production concentrated in a
small area.
The vast majority of our producing properties are geographically
concentrated in two counties in Texas, and our proved reserves
are primarily attributable to one field in that area. As a
result of this concentration, we may be disproportionately
exposed to the impact of delays or interruptions of production
from these wells caused by significant governmental regulation,
transportation capacity constraints, curtailments of production,
natural disasters, interruption of transportation of gas
produced from the wells in these basins or other events that
impact these areas.
Certain of our
undeveloped leasehold acreage is subject to leases and options
that may expire in the near future.
As of December 31, 2006, we held mineral leases in each of
our areas of operations that are still within their original
lease term and are not currently held by production. Unless we
establish commercial production on the properties subject to
these leases, most of these leases will expire between 2008 and
2015. Options covering approximately 12,000 gross acres in
our Cinco Terry project are scheduled to expire before
June 1, 2008. If these leases or options expire, we will
lose our right to develop the related properties.
Identified
drilling locations that we decide to drill may not yield gas or
oil in commercially viable quantities and are susceptible to
uncertainties that could materially alter the occurrence or
timing of their drilling.
Our drilling locations are in various stages of evaluation,
ranging from locations that are ready to be drilled to locations
that will require substantial additional evaluation and
interpretation. There is no way to predict in advance of
drilling and testing whether any particular drilling location
will yield gas or oil in sufficient quantities to recover
drilling or completion costs or to be economically viable. The
use of seismic data and other technologies and the study of
producing fields in the same area will not enable us to know
conclusively before drilling whether gas or oil will be present
or, if present, whether gas or oil will be present in commercial
quantities. The analysis that we perform may not be useful in
predicting the characteristics and potential reserves associated
with our drilling locations. As a result, we may not find
commercially viable quantities of gas and oil.
Our drilling locations represent a significant part of our
growth strategy. Our ability to drill and develop these
locations depends on a number of factors, including gas and oil
prices, costs, the availability of capital, seasonal conditions,
regulatory approvals and drilling results. Because of these
uncertainties, we do not know when the unproved drilling
locations we have identified will be drilled or if they will
ever be drilled or if we will be able to produce gas or oil from
these or any proved drilling locations. As such, our actual
drilling activities may be materially different from those
presently identified, which could adversely affect our business,
results of operations or financial condition.
15
Unless we
replace our gas and oil reserves, our reserves and production
will decline.
Our future gas and oil production depends on our success in
finding or acquiring additional reserves. If we fail to replace
reserves through drilling or acquisitions, our level of
production and cash flows will be affected adversely. In
general, production from gas and oil properties declines as
reserves are depleted, with the rate of decline depending on
reservoir characteristics. Our total proved reserves will
decline as reserves are produced unless we conduct other
successful exploration and development activities or acquire
properties containing proved reserves, or both. Our ability to
make the necessary capital investment to maintain or expand our
asset base of gas and oil reserves would be impaired to the
extent cash flow from operations is reduced and external sources
of capital become limited or unavailable. We may not be
successful in exploring for, developing or acquiring additional
reserves.
Our actual
production, revenues and expenditures related to our reserves
are likely to differ from our estimates of our proved reserves.
We may experience production that is less than estimated and
drilling costs that are greater than estimated in our reserve
reports. These differences may be material.
The proved gas and oil reserve information included in this
prospectus represents estimates. Petroleum engineering is a
subjective process of estimating underground accumulations of
gas and oil that cannot be measured in an exact manner.
Estimates of economically recoverable gas and oil reserves and
of future net cash flows necessarily depend upon a number of
variable factors and assumptions, including:
|
|
|
historical production from the area compared with production
from other similar producing areas;
|
|
|
the assumed effects of regulations by governmental agencies;
|
|
|
assumptions concerning future gas and oil prices; and
|
|
|
assumptions concerning future operating costs, severance and
excise taxes, development costs and workover and remedial costs.
|
Because all reserve estimates are to some degree subjective,
each of the following items may differ materially from those
assumed in estimating proved reserves:
|
|
|
the quantities of gas and oil that are ultimately recovered;
|
|
|
the production and operating costs incurred;
|
|
|
the amount and timing of future development
expenditures; and
|
|
|
future gas and oil prices.
|
As of December 31, 2006, approximately 49% of our proved
reserves were proved undeveloped. Estimates of proved
undeveloped reserves are even less reliable than estimates of
proved developed reserves.
Furthermore, different reserve engineers may make different
estimates of reserves and cash flows based on the same available
data. Our actual production, revenues and expenditures with
respect to reserves will likely be different from estimates and
the differences may be material. The discounted future net cash
flows included in this prospectus should not be considered as
the current market value of the estimated gas and oil reserves
attributable to our properties. As
16
required by the Securities and Exchange Commission, or the SEC,
the estimated discounted future net cash flows from proved
reserves are generally based on prices and costs as of the date
of the estimate, while actual future prices and costs may be
materially higher or lower. Actual future net cash flows also
will be affected by factors such as:
|
|
|
the amount and timing of actual production;
|
|
|
supply and demand for gas and oil;
|
|
|
increases or decreases in consumption; and
|
|
|
changes in governmental regulations or taxation.
|
In addition, the 10% discount factor, which is required by the
SEC to be used to calculate discounted future net cash flows for
reporting purposes, is not necessarily the most appropriate
discount factor based on interest rates in effect from time to
time and risks associated with us or the oil and gas industry in
general.
You should not assume that the present value of future net
revenues from our proved reserves referred to in this prospectus
is the current market value of our estimated gas and oil
reserves. In accordance with SEC requirements, we generally base
the estimated discounted future net cash flows from our proved
reserves on prices and costs on the date of the estimate. Actual
future prices and costs may differ materially from those used in
the present value estimate. If gas prices decline by $1.00 per
Mcf, then our
PV-10
as of
December 31, 2006 would decrease from $179.9 million
to $110.1 million.
We will
require additional capital to fund our future activities. If we
fail to obtain additional capital, we may not be able to
implement fully our business plan, which could lead to a decline
in reserves.
We depend on our ability to obtain financing beyond our cash
flow from operations. Historically, we have financed our
business plan and operations primarily with internally generated
cash flows, borrowings under our revolving credit facility and
issuances of common stock. We also require capital to fund our
capital budget, which is expected to be approximately
$49.3 million for 2007. As of December 31, 2006,
approximately 49% of our total estimated proved reserves were
undeveloped. Recovery of such reserves will require significant
capital expenditures and successful drilling operations. We will
be required to meet our needs from our internally generated cash
flows, debt financings and equity financings.
If our revenues decrease as a result of lower commodity prices,
operating difficulties, declines in reserves or for any other
reason, we may have limited ability to obtain the capital
necessary to sustain our operations at current levels. We may,
from time to time, need to seek additional financing. Our
revolving credit facility contains covenants restricting our
ability to incur additional indebtedness without lender consent.
There can be no assurance that our bank lenders will provide
this consent or as to the availability or terms of any
additional financing. If we incur additional debt, the related
risks that we now face could intensify.
Even if additional capital is needed, we may not be able to
obtain debt or equity financing on terms favorable to us, or at
all. If cash generated by operations and available under our
revolving credit facility is not sufficient to meet our capital
requirements, the failure to obtain additional financing could
result in a curtailment of our operations relating to
exploration and
17
development of our projects, which in turn could lead to a
possible loss of properties and a decline in our gas reserves.
Our bank
lenders can limit our borrowing capabilities, which may
materially impact our operations.
At March 31, 2007, outstanding borrowings under our
revolving credit facility totaled approximately
$52.2 million. We intend to use a portion of the proceeds
from this offering to repay the outstanding balance under our
revolving credit facility. The borrowing base limitation under
our revolving credit facility is redetermined semi-annually.
Redeterminations are based upon information contained in an
engineering report prepared by an independent petroleum
engineering firm, including, without limitation, commodity
prices and reserve levels. In addition, as is typical in the oil
and gas industry, our bank lenders have substantial flexibility
to reduce our borrowing base on the basis of subjective factors.
Upon a redetermination, we could be required to repay a portion
of our outstanding borrowings, including the total face amounts
of all outstanding letters of credit and the amount of all
unpaid reimbursement obligations, to the extent such amounts
exceed the redetermined borrowing base. We may not have
sufficient funds to make such required repayment, which could
result in a default under the terms of the revolving credit
facility and an acceleration of the loan. We intend to finance
our development, acquisition and exploration activities with
cash flow from operations, borrowings under our revolving credit
facility and other financing activities. In addition, we may
significantly alter our capitalization to make future
acquisitions or develop our properties. These changes in
capitalization may significantly increase our level of debt. If
we incur additional debt for these or other purposes, the
related risks that we now face could intensify. A higher level
of debt also increases the risk that we may default on our debt
obligations. Our ability to meet our debt obligations and to
reduce our level of debt depends on our future performance which
will be affected by general economic conditions and financial,
business and other factors. Many of these factors are beyond our
control. Our level of debt affects our operations in several
important ways, including the following:
|
|
|
a portion of our cash flow from operations is used to pay
interest on borrowings;
|
|
|
the covenants contained in the agreements governing our debt
limit our ability to borrow additional funds, pay dividends,
dispose of assets or issue shares of preferred stock and
otherwise may affect our flexibility in planning for, and
reacting to, changes in business conditions;
|
|
|
a high level of debt may impair our ability to obtain additional
financing in the future for working capital, capital
expenditures, acquisitions or general corporate purposes;
|
|
|
a leveraged financial position would make us more vulnerable to
economic downturns and could limit our ability to withstand
competitive pressures; and
|
|
|
any debt that we incur under our revolving credit facility will
be at variable rates which makes us vulnerable to increases in
interest rates.
|
18
The
unavailability or high cost of drilling rigs, equipment,
supplies, personnel and oilfield services could adversely affect
our ability to execute our exploration and development plans on
a timely basis and within our budget.
Our industry is cyclical, and from time to time there is a
shortage of drilling rigs, equipment, supplies and qualified
personnel. During these periods, the costs and delivery times of
rigs, equipment and supplies are substantially greater. As a
result of historically strong prices of gas, the demand for
oilfield and drilling services has risen, and the costs of these
services are increasing. For example, average day rates for land
based rigs have increased substantially during the last two
years. We are particularly sensitive to higher rig costs and
drilling rig availability, as we presently have two rigs under
contract, one of which is on a well-to-well basis. If the
unavailability or high cost of drilling rigs, equipment,
supplies or qualified personnel were particularly severe in the
areas where we operate, we could be materially and adversely
affected.
Competition in
the oil and gas industry is intense, and many of our competitors
have resources that are greater than ours.
We operate in a highly competitive environment for acquiring
prospects and productive properties, marketing gas and oil and
securing equipment and trained personnel. Many of our
competitors are major and large independent oil and gas
companies that possess and employ financial, technical and
personnel resources substantially greater than ours. Those
companies may be able to develop and acquire more prospects and
productive properties than our financial or personnel resources
permit. Our ability to acquire additional prospects and discover
reserves in the future will depend on our ability to evaluate
and select suitable properties and consummate transactions in a
highly competitive environment. Also, there is substantial
competition for capital available for investment in the oil and
gas industry. Larger competitors may be better able to withstand
sustained periods of unsuccessful drilling and absorb the burden
of changes in laws and regulations more easily than we can,
which would adversely affect our competitive position. We may
not be able to compete successfully in the future in acquiring
prospective reserves, developing reserves, marketing
hydrocarbons, attracting and retaining quality personnel and
raising additional capital.
Our customer
base is concentrated, and the loss of our key customer could
therefore adversely affect our financial results.
In 2006, Ozona Pipeline Energy Company, which we refer to as
Ozona Pipeline, accounted for approximately 89.6% of our total
gas and oil sales excluding realized hedge settlements. To the
extent that Ozona Pipeline reduces its purchases in gas or oil
or defaults on its obligations to us, we would be adversely
affected unless we were able to make comparably favorable
arrangements with other customers. Ozona Pipelines default
or non-performance could be caused by factors beyond our
control. A default could occur as a result of circumstances
relating directly to the customer, or due to circumstances
related to other market participants with which the customer has
a direct or indirect relationship.
19
We depend on
our management team and other key personnel. Accordingly, the
loss of any of these individuals could adversely affect our
business, financial condition and the results of operations and
future growth.
Our success largely depends on the skills, experience and
efforts of our management team and other key personnel. The loss
of the services of one or more members of our senior management
team or of our other employees with critical skills needed to
operate our business could have a negative effect on our
business, financial condition, results of operations and future
growth. We have entered into employment agreements with J. Ross
Craft, our President and Chief Executive Officer, Steven P.
Smart, our Executive Vice President and Chief Financial Officer
and Glenn W. Reed, our Senior Vice PresidentOperations.
See Executive compensationOther
benefitsEmployment agreements and other
arrangements. If any of these officers or other key
personnel resign or become unable to continue in their present
roles and are not adequately replaced, our business operations
could be materially adversely affected. Our ability to manage
our growth, if any, will require us to continue to train,
motivate and manage our employees and to attract, motivate and
retain additional qualified personnel. Competition for these
types of personnel is intense, and we may not be successful in
attracting, assimilating and retaining the personnel required to
grow and operate our business profitably.
We are subject
to complex governmental laws and regulations that may adversely
affect the cost, manner or feasibility of doing
business.
Our operations and facilities are subject to extensive federal,
state and local laws and regulations relating to the exploration
for, and the development, production and transportation of, gas
and oil, and operating safety, and protection of the
environment, including those relating to air emissions,
wastewater discharges, land use, storage and disposal of wastes
and remediation of contaminated soil and groundwater. Future
laws or regulations, any adverse changes in the interpretation
of existing laws and regulations or our failure to comply with
existing legal requirements may harm our business, results of
operations and financial condition. We may encounter reductions
in reserves or be required to make large and unanticipated
capital expenditures to comply with governmental laws and
regulations, such as:
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price control;
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taxation;
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lease permit restrictions;
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drilling bonds and other financial responsibility requirements,
such as plug and abandonment bonds;
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spacing of wells;
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unitization and pooling of properties;
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safety precautions; and
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permitting requirements.
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Under these laws and regulations, we could be liable for:
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personal injuries;
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property and natural resource damages;
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well reclamation costs, soil and groundwater remediation
costs; and
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governmental sanctions, such as fines and penalties.
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Our operations could be significantly delayed or curtailed, and
our cost of operations could significantly increase as a result
of environmental safety and other regulatory requirements or
restrictions. We are unable to predict the ultimate cost of
compliance with these requirements or their effect on our
operations. We may be unable to obtain all necessary licenses,
permits, approvals and certificates for proposed projects.
Intricate and changing environmental and other regulatory
requirements may require substantial expenditures to obtain and
maintain permits. If a project is unable to function as planned,
for example, due to costly or changing requirements or local
opposition, it may create expensive delays, extended periods of
non-operation or significant loss of value in a project. See
BusinessRegulation.
Operating
hazards, natural disasters or other interruptions of our
operations could result in potential liabilities, which may not
be fully covered by our insurance.
The oil and gas business involves certain operating hazards such
as:
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well blowouts;
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cratering;
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explosions;
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uncontrollable flows of gas, oil or well fluids;
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fires;
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pollution; and
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releases of toxic gas.
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The occurrence of one of the above may result in injury, loss of
life, suspension of operations, environmental damage and
remediation
and/or
governmental investigations and penalties.
In addition, our operations in Texas are especially susceptible
to damage from natural disasters such as tornados and involve
increased risks of personal injury, property damage and
marketing interruptions. Any of these operating hazards could
cause serious injuries, fatalities or property damage, which
could expose us to liabilities. The payment of any of these
liabilities could reduce, or even eliminate, the funds available
for exploration, development, exploitation and acquisition, or
could result in a loss of our properties. Consistent with
insurance coverage generally available to the industry, our
insurance policies provide limited coverage for losses or
liabilities relating to pollution, with broader coverage for
sudden and accidental occurrences. Our insurance might be
inadequate to cover our liabilities. The insurance market in
general and the energy insurance market in particular have been
difficult markets over the past several years. Insurance costs
are expected to continue to increase over the next few years and
we may decrease coverage and retain more risk to mitigate future
cost increases. If we incur substantial liability and the
damages are not covered by insurance or are in excess of policy
limits, or if we incur liability at a time when we are not able
to obtain liability insurance, then our business, results of
operations and financial condition could be materially adversely
affected.
21
Our results
are subject to quarterly and seasonal
fluctuations.
Our quarterly operating results have fluctuated in the past and
could be negatively impacted in the future as a result of a
number of factors, including:
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seasonal variations in gas and oil prices;
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variations in levels of production; and
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the completion of exploration and production projects.
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Market
conditions or transportation impediments may hinder our access
to gas and oil markets or delay our production.
Market conditions, the unavailability of satisfactory gas and
oil processing and transportation may hinder our access to gas
and oil markets or delay our production. Although currently we
control the pipeline operations for a majority of our production
in the Ozona Northeast field, we do not have such control in
other areas in which we expect to conduct operations. The
availability of a ready market for our gas and oil production
depends on a number of factors, including the demand for and
supply of gas and oil and the proximity of reserves to pipelines
or trucking and terminal facilities. In addition, the amount of
gas and oil that can be produced and sold is subject to
curtailment in certain circumstances, such as pipeline
interruptions due to scheduled and unscheduled maintenance,
excessive pressure, physical damage to the gathering or
transportation system or lack of contracted capacity on such
systems. The curtailments arising from these and similar
circumstances may last from a few days to several months, and in
many cases we are provided with limited, if any, notice as to
when these circumstances will arise and their duration. As a
result, we may not be able to sell, or may have to transport by
more expensive means, the gas and oil production from wells or
we may be required to shut in gas wells or delay initial
production until the necessary gathering and transportation
systems are available. Any significant curtailment in gathering
system or pipeline capacity, or significant delay in
construction of necessary gathering and transportation
facilities, could adversely affect our business, financial
condition or results of operations.
Environmental
liabilities may expose us to significant costs and
liabilities.
There is inherent risk of incurring significant environmental
costs and liabilities in our gas and oil operations due to the
handling of petroleum hydrocarbons and generated wastes, the
occurrence of air emissions and water discharges from
work-related activities and the legacy of pollution from
historical industry operations and waste disposal practices. We
may incur joint and several or strict liability under these
environmental laws and regulations in connection with spills,
leaks or releases of petroleum hydrocarbons and wastes on, under
or from our properties and facilities, many of which have been
used for exploration, production or development activities for
many years, oftentimes by third parties not under our control.
Private parties, including the owners of properties upon which
we conduct drilling and production activities as well as
facilities where our petroleum hydrocarbons or wastes are taken
for reclamation or disposal, may also have the right to pursue
legal actions to enforce compliance as well as to seek damages
for non-compliance with environmental laws and regulations or
for personal injury or property damage. In addition, changes in
environmental laws and regulations occur frequently, and any
such changes that result in more stringent and costly waste
handling, storage, transport, disposal or remediation
requirements could have a material adverse effect on
22
our production or our operations or financial position. We may
not be able to recover some or any of these costs from
insurance. See BusinessRegulationEnvironmental
regulations.
Our growth
strategy could fail or present unanticipated problems for our
business in the future, which could adversely affect our ability
to make acquisitions or realize anticipated benefits of those
acquisitions.
Our growth strategy may include acquiring oil and gas businesses
and properties. We may not be able to identify suitable
acquisition opportunities or finance and complete any particular
acquisition successfully.
Furthermore, acquisitions involve a number of risks and
challenges, including:
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diversion of managements attention;
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the need to integrate acquired operations;
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potential loss of key employees of the acquired companies;
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potential lack of operating experience in a geographic market of
the acquired business; and
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an increase in our expenses and working capital requirements.
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Any of these factors could adversely affect our ability to
achieve anticipated levels of cash flows from the acquired
businesses or realize other anticipated benefits of those
acquisitions.
We engage in
hedging transactions which involve risks that can harm our
business.
To manage our exposure to price risks in the marketing of our
gas and oil production, we enter into gas and oil price hedging
agreements. While intended to reduce the effects of volatile oil
and gas prices, such transactions may limit our potential gains
and increase our potential losses if gas and oil prices were to
rise substantially over the price established by the hedge. In
addition, such transactions may expose us to the risk of loss in
certain circumstances, including instances in which our
production is less than expected, there is a widening of price
differentials between delivery points for our production and the
delivery point assumed in the hedge arrangement or the
counterparties to the hedging agreements fail to perform under
the contracts.
The
requirements of complying with the Securities Exchange Act of
1934 may strain our resources and distract
management.
As a public company we will be subject to the reporting
requirements of the Securities Exchange Act of 1934, referred to
as the Exchange Act, and the Sarbanes Oxley Act of 2002 and
related rules of the SEC. In addition, the NASDAQ Global Market
regulates corporate governance practices of public companies.
These requirements may place a strain on our systems and
resources as we will be required to carry out activities we have
not conducted previously, and we will incur significant legal,
accounting and other expenses that we did not incur in the past.
The Exchange Act requires that we file annual, quarterly and
current reports with respect to our business and financial
condition. The Sarbanes Oxley Act of 2002 requires that we
maintain effective disclosure controls and procedures, corporate
governance standards and internal controls over financial
reporting. For example, under Section 404 of the Sarbanes
Oxley Act, for our annual report on
Form 10-K
for the year ending December 31, 2008, we will need to
document and test our internal control procedures, our
management will need to assess and
23
report on our internal control over financial reporting and our
independent accountants will need to issue an opinion on the
effectiveness of those controls. If we identify any issues in
complying with those requirements (for example, if we or our
independent auditors identify a material weakness or significant
deficiency in our internal control over financial reporting), we
could incur additional costs rectifying those issues, and the
existence of those issues could adversely affect us, our
reputation or investor perceptions of us. We also expect that it
could be difficult and will be significantly more expensive to
obtain directors and officers liability insurance,
and we may be required to accept reduced policy limits and
coverage or incur substantially higher costs to obtain the same
or similar coverage. As a result, it may be more difficult for
us to attract and retain qualified persons to serve on our board
of directors or as executive officers. Advocacy efforts by
stockholders and third parties also may prompt even more changes
in governance and reporting requirements. We cannot predict or
estimate the amount of additional costs we may incur or the
timing of such costs. Additionally, in connection with these
heightened duties, significant resources and management
oversight will be required as we may need to devote additional
time and personnel to legal, financial and accounting activities
to ensure our ongoing compliance with public company reporting
requirements. The effort to prepare for these obligations may
divert managements attention from other business concerns,
which could have a material adverse affect on our business,
financial condition, results of operations or cash flow.
Failure by us
to achieve and maintain effective internal control over
financial reporting in accordance with the rules of the SEC
could harm our business and operating results and/or result in a
loss of investor confidence in our financial reports, which
could in turn have a material adverse effect on our business and
stock price.
Under current rules of the SEC, we will be required to document
and test our internal control over financial reporting so that
our management can certify as to the effectiveness of our
internal control over financial reporting and our independent
registered public accounting firm can render an opinion on the
effectiveness of our internal control over financial reporting.
We are in the process of documenting our internal control
systems to allow management to evaluate and report on, and our
independent auditors to audit, our internal control over
financial reporting. Once the documentation is complete, we will
be performing the system and process evaluation and testing (and
any necessary remediation) required to comply with the
management certification and auditor attestation requirements of
Section 404 of the Sarbanes Oxley Act of 2002. We will be
required to comply with Section 404 for the year ending
December 31, 2008. However, we cannot be certain as to the
timing of completion of our evaluation, testing and remediation
actions or the impact of the same on our operations.
Furthermore, upon completion of this process, we may identify
control deficiencies of varying degrees of severity under
applicable SEC and Public Company Accounting Oversight Board
rules and regulations that remain unremediated. As a public
company, we will be required to report, among other things,
control deficiencies that constitute a material
weakness or changes in internal controls that, or that are
reasonably likely to, materially affect internal control over
financial reporting. A material weakness is a
significant deficiency or combination of significant
deficiencies that results in a reasonable likelihood that a
material misstatement of the annual or interim consolidated
financial statements will not be prevented or detected. If we
fail to implement the requirements of Section 404 in a
timely manner, we might be subject to sanctions or investigation
by regulatory authorities such as the SEC. In addition, failure
to comply with Section 404 or the report by us of a
material weakness may cause investors to lose confidence in our
consolidated financial statements, and our stock price may be
adversely
24
affected as a result. If we fail to remedy any material
weakness, our consolidated financial statements may be
inaccurate, we may face restricted access to the capital markets
and our stock price may be adversely affected.
We have three
affiliated stockholders with a controlling interest in our
company, whose interests may differ from your interests and who
will be able to determine the outcome of matters voted upon by
our stockholders.
Yorktown Energy Partners V, L.P., Yorktown Energy Partners
VI, L.P. and Yorktown Energy Partners VII, L.P., or
collectively, Yorktown, which are under common management, own
approximately % of our outstanding
common stock. After giving effect to this offering, Yorktown
will continue to beneficially own
approximately % of our outstanding
common stock in the aggregate ( %
if the underwriters over-allotment option is exercised in
full). In addition, one Yorktown representative serves on our
board of directors, and our officers will beneficially own or
control approximately % of our
common stock outstanding ( % if the
underwriters over-allotment option is exercised in full).
See Security ownership of certain beneficial owners and
management. As a result of this ownership, Yorktown will
have the ability to control the vote in any election of
directors. Yorktown also will have control over our decisions to
enter into significant corporate transactions and, in its
capacity as our majority stockholder, will have the ability to
prevent any transactions that it does not believe are in
Yorktowns best interest. As a result, Yorktown will be
able to control, directly or indirectly and subject to
applicable law, all matters affecting us, including the
following:
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any determination with respect to our business direction and
policies, including the appointment and removal of officers;
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any determinations with respect to mergers, business
combinations or dispositions of assets;
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our capital structure;
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compensation, option programs and other human resources policy
decisions;
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changes to other agreements that may adversely affect
us; and
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the payment, or nonpayment, of dividends on our common stock.
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Yorktown also may have an interest in pursuing transactions
that, in their judgment, enhance the value of their respective
equity investments in our company, even though those
transactions may involve risks to you as a minority stockholder.
In addition, circumstances could arise under which their
interests could be in conflict with the interests of our other
stockholders or you, a minority stockholder. Also, Yorktown and
their affiliates have and may in the future make significant
investments in other companies, some of which may be
competitors. Yorktown and its affiliates are not obligated to
advise us of any investment or business opportunities of which
they are aware, and they are not restricted or prohibited from
competing with us.
We have
renounced any interest in specified business opportunities, and
certain members of our board of directors and certain of our
stockholders generally have no obligation to offer us those
opportunities.
In accordance with Delaware law, we have renounced any interest
or expectancy in any business opportunity, transaction or other
matter in which our non-employee directors and certain of our
stockholders, each referred to as a Designated Party,
participates or desires to participate in
25
that involves any aspect of the exploration and production
business in the oil and industry. If any such business
opportunity is presented to a Designated Person who also serves
as a member of our board of directors, the Designated Party has
no obligation to communicate or offer that opportunity to us,
and the Designated Party may pursue the opportunity as he sees
fit, unless:
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it was presented to the Designated Party solely in that
persons capacity as a director of our company and with
respect to which, at the time of such presentment, no other
Designated Party has independently received notice of or
otherwise identified the business opportunity; or
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the opportunity was identified by the Designated Party solely
through the disclosure of information by or on behalf of us.
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For a more complete discussion of this agreement, please read
Certain relationships and related party
transactionsBusiness opportunities renunciation. As
a result of this renunciation, our non-employee directors should
not be deemed to be breaching any fiduciary duty to us if they
or their affiliates or associates pursue opportunities as
described above and our future competitive position and growth
potential could be adversely affected.
Severe weather
could have a material adverse impact on our
business.
Our business could be materially and adversely affected by
severe weather. Repercussions of severe weather conditions may
include:
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curtailment of services;
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weather-related damage to drilling rigs, resulting in suspension
of operations;
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weather-related damage to our facilities;
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inability to deliver materials to jobsites in accordance with
contract schedules; and
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loss of productivity.
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A terrorist
attack or armed conflict could harm our business.
Terrorist activities, anti-terrorist efforts and other armed
conflict involving the United States may adversely affect the
United States and global economies and could prevent us from
meeting our financial and other obligations. If any of these
events occur or escalate, the resulting political instability
and societal disruption could reduce overall demand for gas and
oil, potentially putting downward pressure on demand for our
services and causing a reduction in our revenue. Gas and oil
related facilities could be direct targets for terrorist
attacks, and our operations could be adversely impacted if
significant infrastructure or facilities we use for the
production, transportation or marketing of our gas and oil
production are destroyed or damaged. Costs for insurance and
other security may increase as a result of these threats, and
some insurance coverage may become difficult to obtain, if
available at all.
26
Risks related to
this offering
There has been
no public market for our common stock, and our stock price may
fluctuate significantly.
There is currently no public market for our common stock, and an
active trading market may not develop or be sustained after the
sale of all of the shares covered by this prospectus. The market
price of our common stock could fluctuate significantly as a
result of:
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our operating and financial performance and prospects;
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quarterly variations in the rate of growth of our financial
indicators, such as net income per share, net income and
revenues;
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changes in revenue or earnings estimates or publication of
research reports by analysts about us or the exploration and
production industry;
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liquidity and registering our common stock for public resale;
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actual or unanticipated variations in our reserve estimates and
quarterly operating results;
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changes in gas and oil prices;
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speculation in the press or investment community;
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sales of our common stock by our stockholders;
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increases in our cost of capital;
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changes in applicable laws or regulations, court rulings and
enforcement and legal actions;
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changes in market valuations of similar companies;
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adverse market reaction to any increased indebtedness we incur
in the future;
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additions or departures of key management personnel;
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actions by our stockholders;
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general market and economic conditions, including the occurrence
of events or trends affecting the price of gas; and
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domestic and international economic, legal and regulatory
factors unrelated to our performance.
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If a trading market develops for our common stock, stock markets
in general experience volatility that often is unrelated to the
operating performance of particular companies. These broad
market fluctuations may adversely affect the trading price of
our common stock.
We do not
anticipate paying any dividends on our common stock in the
foreseeable future.
We do not expect to declare or pay any cash or other dividends
in the foreseeable future on our common stock, as we intend to
use cash flow generated by operations to expand our business.
Our revolving credit facility will restrict our ability to pay
cash dividends on our common stock, and we may also enter into
credit agreements or other borrowing arrangements in the future
that restrict or limit our ability to pay cash dividends on our
common stock.
27
Certain
stockholders shares are restricted from immediate resale
but may be sold into the market in the near future. This could
cause the market price of our common stock to drop
significantly.
After this offering, we will have
outstanding shares
of common stock. Of these shares,
the shares
we and the selling stockholder are selling in this offering,
or shares
if the underwriters exercise their over-allotment option in
full, will be freely tradeable without restriction under the
Securities Act except for any shares purchased by one of our
affiliates as defined in Rule 144 under the
Securities Act. A total
of shares,
or shares
if the underwriters exercise their over-allotment option in
full, will be restricted securities (within the
meaning of Rule 144 under the Securities Act) or subject to
lock-up
arrangements. In connection with this offering, we, our
executive officers and directors and the other holders of our
common stock (including the selling stockholder) have agreed
that, during the period beginning from the date of this
prospectus and continuing to and including the day 180 days
after the date of this prospectus, neither we nor any of them
will, directly or indirectly, offer, sell, offer to sell,
contract to sell or otherwise dispose of any shares of our
common stock without the prior written consent of
J.P. Morgan Securities Inc., on behalf of the underwriters,
except in limited circumstances. See Underwriting
for a description of these
lock-up
arrangements. An aggregate
of
of these shares will become available for resale in the public
market as shown in the chart below.
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Number
of shares
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Date
of eligibility for resale into public market
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No less than 180 days after
the date of this prospectus
(in accordance with lock-up agreements with the underwriters).
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Between 181 and 365 days
after the date of this prospectus due to the requirements of the
federal securities laws.
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Sales of a substantial number of shares of our common stock in
the public markets following this offering by any of our
existing stockholders (or persons to whom our existing
stockholders may distribute shares of our common stock), or the
perception that such sales might occur, could have a material
adverse effect on the price of our common stock or could impair
our ability to obtain capital through an offering of equity
securities.
As soon as practicable after this offering, we intend to file
one or more registration statements with the SEC on
Form S-8
providing for the registration
of shares
of our common stock issued or reserved for issuance under our
stock incentive plan. Subject to the exercise of unexercised
options or the expiration or waiver of vesting conditions for
restricted stock and the expiration of
lock-ups
we
and certain of our stockholders have entered into, shares
registered under these registration statements on
Form S-8
will be available for resale immediately in the public market
without restriction.
You may
experience dilution of your ownership interests due to the
future issuance of additional shares of our common
stock.
We may in the future issue our previously authorized and
unissued securities, resulting in the dilution of the ownership
interests of our present stockholders and purchasers of common
stock offered hereby. We are currently authorized to issue
90 million shares of common stock and 10 million
shares of preferred stock with preferences and rights as
determined by our board of directors. The potential issuance of
such additional shares of common stock may create downward
pressure on the trading price of our common stock. We may also
issue additional
28
shares of our common stock or other securities that are
convertible into or exercisable for common stock in connection
with the hiring of personnel, future acquisitions, future public
offerings or private placements of our securities for capital
raising purposes, or for other business purposes.
If equity
research analysts do not publish research or reports about our
business or if they issue unfavorable commentary or downgrade
our common stock, the price of our common stock could
decline.
The trading market for our common stock may rely in part on the
research and reports that equity research analysts publish about
us and our business. We do not control the opinions of these
analysts. The price of our stock could decline if one or more
equity analysts downgrade our stock or if those analysts issue
other unfavorable commentary or cease publishing reports about
us or our business.
The
availability of shares for sale in the future could reduce the
market price of our common stock.
In the future, we may issue securities to raise cash for
acquisitions. We may also acquire interests in outside companies
by using a combination of cash and our common stock or just our
common stock. We may also issue securities convertible into our
common stock. Any of these events may dilute your ownership
interest in our company and have an adverse impact on the price
of our common stock.
In addition, sales of a substantial amount of our common stock
in the public market, or the perception that these sales may
occur, could reduce the market price of our common stock. This
could also impair our ability to raise additional capital
through the sale of our securities.
Certain
provisions of Delaware law, our restated certificate of
incorporation and our restated bylaws could hinder, delay or
prevent a change in control of our company, which could
adversely affect the price of our common stock.
Certain provisions of Delaware law, our restated certificate of
incorporation and our restated bylaws have the effect of
discouraging, delaying or preventing transactions that involve
an actual or threatened change in control of our company.
Delaware law imposes restrictions on mergers and other business
combinations between us and any holder of 15% or more of our
outstanding common stock. In addition, our restated certificate
of incorporation and restated bylaws include the following
provisions:
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Written consent of stockholders.
Our restated
certificate of incorporation and restated bylaws provide that
any action required or permitted to be taken by our stockholders
must be taken at a duly called meeting of stockholders and not
by written consent.
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Call of special meetings of stockholders.
Our
restated bylaws provide that special meetings of stockholders
may be called at any time only by our board of directors,
chairman or Chief Executive Officer and not the stockholders.
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Classified board of directors.
Our board of
directors will be divided into three classes with staggered
terms of office of three years each. The classification and
staggered terms of office of our directors make it more
difficult for a third party to gain control of our board of
directors. At least two annual meetings of stockholders, instead
of one, generally would be required to effect a change in a
majority of the board of directors.
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Removal of directors.
Under our restated certificate
of incorporation, a director may be removed only for cause and
only by the affirmative vote of at least 67% of the voting power
of the outstanding shares of our capital stock.
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Number of directors, board vacancies, term of
office.
Our restated certificate of incorporation and
our restated bylaws provide that only the board of directors may
set the number of directors. We have elected to be subject to
certain provisions of Delaware law which vest in the board of
directors the exclusive right, by the affirmative vote of a
majority of the remaining directors, to fill vacancies on the
board even if the remaining directors do not constitute a
quorum. When effective, these provisions of Delaware law, which
are applicable even if other provisions of Delaware law or the
charter or bylaws provide to the contrary, also provide that any
director elected to fill a vacancy shall hold office for the
remainder of the full term of the class of directors in which
the vacancy occurred, rather than the next annual meeting of
stockholders as would otherwise be the case, and until his or
her successor is elected and qualifies.
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Advance notice provisions for stockholder nominations and
proposals
. Our restated bylaws require advance written
notice for stockholders to nominate persons for election as
directors at, or to bring other business before, any meeting of
stockholders. This bylaw provision limits the ability of
stockholders to make nominations of persons for election as
directors or to introduce other proposals unless we are notified
in a timely manner prior to the meeting.
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Amending the bylaws.
Our restated certificate of
incorporation permits our board of directors to adopt, alter or
repeal any provision of the restated bylaws or to make new
bylaws. Our restated certificate of incorporation also provides
that our restated bylaws may be amended by the affirmative vote
of the holders of at least 67% of the voting power of the
outstanding shares of our capital stock.
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Authorized but unissued shares.
Under our restated
certificate of incorporation, our board of directors has
authority to cause the issuance of preferred stock from time to
time in one or more series and to establish the terms,
preferences and rights of any such series of preferred stock,
all without approval of our stockholders. Nothing in our
restated certificate of incorporation precludes future issuances
without stockholder approval of the authorized but unissued
shares of our common stock.
|
See Description of capital stockAnti-takeover
effects of provisions of Delaware law, our restated certificate
of incorporation and restated bylaws. Any one or more of
these factors could have the effect of delaying or preventing a
change in control or the removal of management, and deterring
potential acquirers from making an offer to our stockholders,
even if that event potentially would be favorable to the
interests of our stockholders.
Purchasers of
common stock in this offering will experience immediate and
substantial dilution of $ per
share.
Based on an assumed initial public offering price of
$ per share, purchasers of our
common stock in this offering will experience an immediate and
substantial dilution of $ per
share in the as adjusted pro forma net tangible book value per
share of common stock from the initial public offering price,
and our pro forma as adjusted net tangible book value as of
December 31, 2006 after giving effect to this offering
would be $ per share. See
Dilution.
30
Cautionary
statement regarding
forward-looking statements
Various statements in this prospectus, including those that
express a belief, expectation or intention, as well as those
that are not statements of historical fact, are forward-looking
statements. The forward-looking statements may include
projections and estimates concerning the timing and success of
specific projects and our future reserves, production, revenues,
income and capital spending. When we use the words
believe, intend, expect,
may, should, anticipate,
could, estimate, plan,
predict, project or their negatives,
other similar expressions or the statements that include those
words, it usually is a forward-looking statement.
The forward-looking statements contained in this prospectus are
largely based on our expectations, which reflect estimates and
assumptions made by our management. These estimates and
assumptions reflect our best judgment based on currently known
market conditions and other factors. Although we believe such
estimates and assumptions to be reasonable, they are inherently
uncertain and involve a number of risks and uncertainties that
are beyond our control. In addition, managements
assumptions about future events may prove to be inaccurate.
Management cautions all readers that the forward-looking
statements contained in this prospectus are not guarantees of
future performance, and we cannot assure any reader that such
statements will be realized or the forward-looking events and
circumstances will occur. Actual results may differ materially
from those anticipated or implied in the forward-looking
statements due to the factors listed in the Risk
factors section and elsewhere in this prospectus. All
forward-looking statements speak only as of the date of this
prospectus. We do not intend to publicly update or revise any
forward-looking statements as a result of new information,
future events or otherwise. These cautionary statements qualify
all forward-looking statements attributable to us, or persons
acting on our behalf. The risks, contingencies and uncertainties
relate to, among other matters, the following:
|
|
|
our business strategy;
|
|
|
estimated quantities of gas and oil reserves;
|
|
|
technology;
|
|
|
our financial position;
|
|
|
our cash flow and liquidity;
|
|
|
declines in the prices we receive for our gas and oil affecting
our operating results and cash flow;
|
|
|
economic slowdowns that can adversely affect consumption of gas
and oil by businesses and consumers;
|
|
|
uncertainties in estimating our gas and oil reserves;
|
|
|
replacing our gas and oil reserves;
|
|
|
uncertainties in exploring for and producing gas and oil;
|
|
|
our inability to obtain additional financing necessary to fund
our operations and capital expenditures and to meet our other
obligations;
|
31
|
|
|
availability of drilling and production equipment and field
service providers;
|
|
|
disruptions to, capacity constraints in or other limitations on
the pipeline systems which deliver our gas and other processing
and transportation considerations;
|
|
|
competition in the oil and gas industry;
|
|
|
marketing of gas and oil;
|
|
|
exploitation or property acquisitions;
|
|
|
our inability to retain and attract key personnel;
|
|
|
the effects of government regulation and permitting and other
legal requirements;
|
|
|
costs associated with perfecting title for mineral rights in
some of our properties;
|
|
|
plans, objectives, expectations and intentions contained in this
prospectus that are not historical; and
|
|
|
other factors discussed under Risk factors.
|
32
Use of
proceeds
We estimate that the net proceeds to us from the sale of common
stock in this offering will be approximately
$ million (or
$ million if the underwriters
exercise their over-allotment option in full), in each case
based on an offering price of $
per share, the mid-point of the estimated price range shown on
the front cover of this prospectus, and after deducting the
underwriting discounts and the estimated offering expenses of
$ payable by us. Each dollar
increase (decrease) in the per share offering price will
increase (decrease) the amount of net proceeds we receive from
this offering by $ .
We intend to use the net proceeds of this offering to repay
approximately $ million
outstanding under our revolving credit facility, to
repurchase shares of our common
stock held by Neo Canyon Exploration, L.P. at a purchase price
of $ million and the
remainder for general corporate purposes, including exploration
and development activities, gas and oil reserves and leasehold
acquisitions in the ordinary course of business and for working
capital.
At March 31, 2007, outstanding borrowings under our
revolving credit facility totaled approximately
$52.2 million with an interest rate of 7.02%. We incurred
the debt under our revolving credit facility principally to meet
our capital expenditure requirements and other working capital
needs. We will have no outstanding borrowings under our
revolving credit facility after the closing of this offering,
leaving us with approximately
$ million available for
future borrowings under such revolving credit facility. See
Managements discussion and analysis of financial
condition and results of operationsCredit facility
for a description of our revolving credit facility.
We will not receive any proceeds from the sale of shares of
common stock by the selling stockholder.
Dividend
policy
We do not expect to pay any cash or other dividends in the
foreseeable future on our common stock, as we intend to reinvest
cash flow generated by operations in our business. Our revolving
credit facility currently restricts our ability to pay cash
dividends on our common stock, and we may also enter into credit
agreements or other borrowing arrangements in the future that
restrict or limit our ability to pay cash dividends on our
common stock.
33
Capitalization
The following table sets forth our cash and cash equivalents and
capitalization as of March 31, 2007:
|
|
|
on an actual historical basis;
|
|
|
on a pro forma basis, reflecting the consummation of the
transactions described under Certain relationships and
related party transactionsThe contribution agreement
and our
for
common stock split; and
|
|
|
on a pro forma as adjusted basis, reflecting the consummation of
the transactions described under Certain relationships and
related party transactionsThe contribution
agreement,
our
for
common stock split and the sale
of shares
of common stock in this offering at an assumed initial public
offering price of $ per share,
after deducting underwriting discounts and estimated offering
expenses payable by us and the application of the estimated net
proceeds from this offering as set forth under Use of
proceeds.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As of
March 31, 2007
|
|
|
|
|
|
|
Pro forma
|
(in
thousands)
|
|
Actual
|
|
Pro
forma
|
|
as
adjusted
|
|
|
Cash and cash equivalents
|
|
$
|
5,374
|
|
$
|
|
|
$
|
|
|
|
|
|
|
|
Long-term debt
|
|
$
|
52,169
|
|
$
|
|
|
$
|
|
Stockholders equity:
|
|
|
|
|
|
|
|
|
|
Preferred stock, $0.01 par value,
10,000,000 shares authorized, no shares issued and outstanding
actual, no shares issued and outstanding pro forma, no shares
issued and outstanding pro forma as adjusted
|
|
|
|
|
|
|
|
|
|
Common stock, $0.01 par value,
90,000,000 shares authorized, 3,002,085 shares issued
and outstanding
actual, shares
issued and outstanding pro
forma, shares
issued and outstanding pro forma as adjusted
|
|
|
30
|
|
|
|
|
|
|
Additional paid-in capital
|
|
|
38,883
|
|
|
|
|
|
|
Retained earnings
|
|
|
30,077
|
|
|
|
|
|
|
|
|
|
|
|
|
Total stockholders equity
|
|
$
|
68,990
|
|
$
|
|
|
$
|
|
|
|
|
|
|
|
Total capitalization
|
|
$
|
121,159
|
|
$
|
|
|
$
|
|
|
|
34
Dilution
Purchasers of common stock in this offering will experience
immediate and substantial dilution in the net tangible book
value per share of the common stock for accounting purposes. Net
tangible book value per share is determined by dividing our
tangible net worth (tangible assets less total liabilities) by
the total number of outstanding shares of common stock. At
March 31, 2007, after giving effect to the transactions
described under Certain relationships and related party
transactionsThe contribution agreement and
our
for
common stock split, the pro forma net tangible book value per
share of our common stock was $ ,
or $ per share of common stock.
After giving effect to the sale
of shares
of common stock in this offering and assuming the receipt of the
estimated net proceeds, after deducting the underwriters
discounts and estimated offering expenses, our pro forma as
adjusted net tangible book value at March 31, 2007 would
have been approximately $ , or
$ per share. This represents an
immediate and substantial increase in the pro forma as adjusted
net tangible book value of $ per
share to existing stockholders and an immediate dilution of
$ per share to new investors
purchasing common stock in this offering, resulting from the
difference between the initial public offering price and the pro
forma as adjusted net tangible book value after this offering.
The following table illustrates the per share dilution to new
investors purchasing common stock in this offering:
|
|
|
|
|
|
|
|
Assumed initial public offering
price per share(1)
|
|
|
|
|
$
|
|
Adjusted net tangible book value
per share at March 31, 2007(2)
|
|
$
|
|
|
|
|
Increase per share attributable to
new public investors(3)
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
As adjusted net tangible book
value per share after this offering(3)
|
|
|
|
|
$
|
|
|
|
|
|
|
|
|
Dilution in as adjusted net
tangible book value per share to new investors
|
|
|
|
|
$
|
|
|
|
|
|
|
(1)
|
|
Before deduction of underwriting
discounts and estimated offering expenses.
|
|
(2)
|
|
Net tangible book value is defined
as stockholders equity less intangible assets.
|
|
(3)
|
|
Takes in to account underwriting
discounts and commissions and estimated offering expenses.
|
A $1.00 increase (decrease) in the assumed public offering price
of $ would increase (decrease) our
as adjusted net tangible book value per share after this
offering by $ per share and the
dilution in net tangible book value to new investors by
$ per share, assuming the number
of shares offered by us, as set forth on the cover of this
preliminary prospectus, remains the same and after deducting
estimated underwriting discounts and estimated offering expenses
payable by us.
35
The following table sets forth, on the pro forma as adjusted
basis set forth above as of March 31, 2007, the total
number of shares of common stock owned by existing stockholders
and to be owned by new investors, the total consideration paid
and the average price per share paid by our existing
stockholders and to be paid by new investors in this offering
calculated before deduction of estimated underwriting discounts:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Shares
purchased
|
|
Total
consideration
|
|
Average price
|
|
|
Number
|
|
Percent
|
|
Amount
|
|
Percent
|
|
per
share
|
|
|
Existing stockholders(1)(2)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
New investors(3)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
|
|
|
100%
|
|
|
|
|
|
100%
|
|
|
|
|
|
|
|
|
(1)
|
|
Reflects ownership of shares to be
sold by selling stockholder prior to this offering.
|
|
(2)
|
|
With respect to our executive
officers, directors and 10%-or-greater stockholders, the number
of shares of common stock purchased from us, the total
consideration paid to us and the average price per share paid by
all of those affiliated persons, are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Shares
purchased
|
|
Total
consideration
|
|
Average price
|
|
|
Number
|
|
Percent
|
|
Amount
|
|
Percent
|
|
per
share
|
|
|
Affiliated persons
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(3)
|
|
Excludes shares being sold by the
selling stockholder.
|
If the underwriters over-allotment option to purchase
additional shares is exercised in full, the number of shares
held by new investors will be increased
to
or
approximately
of the total number of shares of common stock outstanding
immediately following this offering.
The preceding tables
exclude shares
of common stock subject to options outstanding as of
March 31, 2007, which have a weighted average exercise
price of $ per share. As of
March 31, 2007, options to
purchase shares
of our common stock were currently exercisable. If these options
were exercised at the average exercise price, the additional
dilution per share to new investors would be
$ .
As
of ,
2007, there
were shares
of our common stock outstanding held by stockholders. Sales by
the selling stockholder in this offering will reduce the number
of shares of common stock held by existing stockholders
to or
approximately % of the total number
of shares of common stock outstanding after this offering and
will increase the number of shares of common stock held by new
investors
by
to approximately % of the total
number of shares of common stock outstanding after this offering.
36
Unaudited
combined pro forma financial data
The following combined pro forma financial information gives
effect to the following transactions:
|
|
|
The issuance of 1,413,081 shares of Approach Resources Inc.
common stock to Neo Canyon Exploration, L.P. for its 30% working
interest in the Ozona Northeast field that Approach does not
already own; and
|
|
|
The issuance of 329,719 shares of Approach Resources Inc.
common stock in exchange for 150,000 shares of Approach
Oil & Gas Inc. common stock, representing all of the
issued and outstanding shares of Approach Oil & Gas
Inc. common stock.
|
Our operations are currently conducted by two separate operating
entities under common control: Approach Resources Inc. and
Approach Oil & Gas Inc. Pursuant to a contribution
agreement, the operations of Approach Oil & Gas Inc.
will be combined under Approach Resources Inc., and we will also
acquire the Neo Canyon interest immediately prior to the closing
of this offering.
The combined pro forma balance sheet as of March 31, 2007
is based on our unaudited combined balance sheet as of
March 31, 2007, appearing elsewhere in this prospectus, and
gives effect to the transactions described above as if they
occurred on March 31, 2007.
The combined pro forma statement of operations for the three
months ended March 31, 2007 is based on our unaudited
combined statement of operations for the three months ended
March 31, 2007 and the unaudited Historical Summary of
Revenues and Direct Operating Expenses of Properties to be
Acquired by Approach Resources Inc. for the three months ended
March 31, 2007, both of which appear elsewhere in this
prospectus, and gives effect to the transactions described above
as if they occurred on January 1, 2007.
The combined pro forma statement of operations for the year
ended December 31, 2006 is based on our audited combined
statement of operations for the year ended December 31,
2006, and the audited Historical Summary of Revenues and Direct
Operating Expenses of Properties to be Acquired by Approach
Resources Inc. for the year ended December 31, 2006, both
of which appear elsewhere in this prospectus, and gives effect
to the transactions described above as if they occurred on
January 1, 2006.
The unaudited combined pro forma financial statements presented
herein have been included as required by the rules of the
Securities and Exchange Commission and are provided for
comparative purposes only. These unaudited combined pro forma
financial statements should be read in conjunction with our
historical combined financial statements and related notes for
the periods presented.
The unaudited combined pro forma financial statements presented
herein are based upon assumptions and include adjustments as
explained in the notes to the unaudited combined pro forma
financial statements, and the actual recording of the
transactions could differ. The unaudited combined pro forma
financial statements presented herein are not necessarily
indicative of the financial results that would have occurred had
the transactions described above occurred on the dates indicated
and should not be viewed as indicative of operations in the
future. However, management believes that the assumptions used
provide a reasonable basis for presenting the significant
effects of the transactions discussed above and that the pro
forma adjustments give appropriate effect to those assumptions.
37
Approach
Resources Inc.
Unaudited combined pro forma balance sheet
March 31, 2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Approach
|
|
|
|
|
|
|
|
|
|
Resources Inc.
|
|
|
|
|
|
|
|
|
|
combined
|
|
|
|
|
|
Combined
|
|
|
|
historical
|
|
|
Pro forma
|
|
|
pro forma
|
|
(in
thousands)
|
|
amounts
|
|
|
adjustments
|
|
|
amounts
|
|
|
|
Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
Current assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$
|
5,374
|
|
|
$
|
|
|
|
$
|
5,374
|
|
Accounts receivable:
|
|
|
|
|
|
|
|
|
|
|
|
|
Joint interest owners
|
|
|
2,463
|
|
|
|
|
|
|
|
2,463
|
|
Oil and gas sales
|
|
|
3,461
|
|
|
|
|
|
|
|
3,461
|
|
Prepaid expenses and other current
assets
|
|
|
852
|
|
|
|
|
|
|
|
852
|
|
|
|
|
|
|
|
Total current assets
|
|
|
12,150
|
|
|
|
|
|
|
|
12,150
|
|
Property and equipment:
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil and gas properties, using the
successful efforts method of accounting
|
|
|
164,726
|
|
|
|
69,463
|
(a)
|
|
|
234,189
|
|
Furniture, fixtures and equipment
|
|
|
256
|
|
|
|
|
|
|
|
256
|
|
Less accumulated depreciation,
depletion and amortization
|
|
|
(26,859
|
)
|
|
|
|
|
|
|
(26,859
|
)
|
|
|
|
|
|
|
Net property and equipment
|
|
|
138,123
|
|
|
|
69,463
|
|
|
|
207,586
|
|
Other assets
|
|
|
119
|
|
|
|
|
|
|
|
119
|
|
|
|
|
|
|
|
Total assets
|
|
$
|
150,392
|
|
|
$
|
69,463
|
|
|
$
|
219,855
|
|
|
|
|
|
|
|
Liabilities and stockholders
equity
|
|
|
|
|
|
|
|
|
|
|
|
|
Current liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Accounts payable
|
|
$
|
5,065
|
|
|
$
|
|
|
|
$
|
5,065
|
|
Oil and gas payables
|
|
|
5,407
|
|
|
|
|
|
|
|
5,407
|
|
Accrued liabilities
|
|
|
971
|
|
|
|
|
|
|
|
971
|
|
Unrealized loss on commodity
derivatives
|
|
|
121
|
|
|
|
|
|
|
|
121
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
11,564
|
|
|
|
|
|
|
|
11,564
|
|
Non-current liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Long-term debt
|
|
|
52,169
|
|
|
|
|
|
|
|
52,169
|
|
Deferred income taxes
|
|
|
17,514
|
|
|
|
|
|
|
|
17,514
|
|
Asset retirement obligations
|
|
|
155
|
|
|
|
63
|
(a)
|
|
|
218
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
81,402
|
|
|
|
63
|
|
|
|
81,465
|
|
Stockholders equity:
|
|
|
|
|
|
|
|
|
|
|
|
|
Common stock
|
|
|
30
|
|
|
|
14
|
(a)
|
|
|
|
|
|
|
|
|
|
|
|
2
|
(b)
|
|
|
46
|
|
Additional paid-in capital
|
|
|
38,883
|
|
|
|
69,386
|
(a)
|
|
|
|
|
|
|
|
|
|
|
|
(2
|
)(b)
|
|
|
108,267
|
|
Retained earnings
|
|
|
30,077
|
|
|
|
|
|
|
|
30,077
|
|
|
|
|
|
|
|
Total stockholders equity
|
|
|
68,990
|
|
|
|
69,400
|
|
|
|
138,390
|
|
|
|
|
|
|
|
Total liabilities and
stockholders equity
|
|
$
|
150,392
|
|
|
$
|
69,463
|
|
|
$
|
219,855
|
|
|
See accompanying
notes.
38
Approach
Resources Inc.
Unaudited combined pro forma statement of operations
Three months ended March 31, 2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Approach
|
|
|
|
|
|
|
|
|
|
|
|
Resources Inc.
|
|
|
|
|
|
|
|
|
|
|
|
combined
|
|
|
Neo Canyon
|
|
|
|
|
Combined
|
|
(in
thousands, except shares and per share
|
|
historical
|
|
|
historical
|
|
Pro
forma
|
|
|
pro
forma
|
|
data)
|
|
amounts
|
|
|
amounts
|
|
adjustments
|
|
|
amounts
|
|
|
|
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil and gas sales
|
|
$
|
11,547
|
|
|
$
|
3,802
|
|
$
|
|
|
|
$
|
15,349
|
|
Overhead and services income
|
|
|
133
|
|
|
|
|
|
|
(101
|
)(c)
|
|
|
32
|
|
|
|
|
|
|
|
Total revenues
|
|
|
11,680
|
|
|
|
3,802
|
|
|
(101
|
)
|
|
|
15,381
|
|
Expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating
|
|
|
979
|
|
|
|
437
|
|
|
|
|
|
|
1,416
|
|
Severance and production taxes
|
|
|
375
|
|
|
|
151
|
|
|
|
|
|
|
526
|
|
Exploration
|
|
|
623
|
|
|
|
|
|
|
|
|
|
|
623
|
|
General and administrative
|
|
|
1,646
|
|
|
|
|
|
|
|
|
|
|
1,646
|
|
Accretion of discount on asset
retirement obligations
|
|
|
3
|
|
|
|
|
|
|
|
|
|
|
3
|
|
Depreciation, depletion and
amortization
|
|
|
3,088
|
|
|
|
|
|
|
1,649
|
(d)
|
|
|
4,737
|
|
|
|
|
|
|
|
Total expenses
|
|
|
6,714
|
|
|
|
588
|
|
|
1,649
|
|
|
|
8,951
|
|
|
|
|
|
|
|
Operating income
|
|
|
4,966
|
|
|
|
3,214
|
|
|
(1,750
|
)
|
|
|
6,430
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense, net
|
|
|
(956
|
)
|
|
|
|
|
|
|
|
|
|
(956
|
)
|
Change in fair value of commodity
derivatives
|
|
|
(4,626
|
)
|
|
|
|
|
|
|
|
|
|
(4,626
|
)
|
|
|
|
|
|
|
Total other income (expense)
|
|
|
(5,582
|
)
|
|
|
|
|
|
|
|
|
|
(5,582
|
)
|
|
|
|
|
|
|
Income (loss) before provision
(benefit) for income taxes
|
|
|
(616
|
)
|
|
|
3,214
|
|
|
(1,750
|
)
|
|
|
848
|
|
Provision (benefit) for income
taxes
|
|
|
(35
|
)
|
|
|
|
|
|
508
|
(e)
|
|
|
473
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$
|
(581
|
)
|
|
$
|
3,214
|
|
$
|
(2,258
|
)
|
|
$
|
375
|
|
|
|
|
|
|
|
Earnings (loss) per share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
(0.19
|
)
|
|
|
|
|
|
|
|
|
$
|
0.08
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
$
|
(0.19
|
)
|
|
|
|
|
|
|
|
|
$
|
0.08
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares
outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
2,987,411
|
|
|
|
|
|
|
1,592,800
|
(g)
|
|
|
4,580,211
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
2,987,411
|
|
|
|
|
|
|
1,706,030
|
(h)
|
|
|
4,693,441
|
|
|
See accompanying
notes.
39
Approach
Resources Inc.
Unaudited combined pro forma statement of operations
Year ended December 31, 2006
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Approach
|
|
|
|
|
|
|
|
|
|
|
|
Resources Inc.
|
|
|
|
|
|
|
|
|
|
|
|
combined
|
|
|
Neo Canyon
|
|
|
|
|
Combined
|
|
|
|
historical
|
|
|
historical
|
|
Pro forma
|
|
|
pro forma
|
|
(in
thousands, except shares and per share data)
|
|
amounts
|
|
|
amounts
|
|
adjustments
|
|
|
amounts
|
|
|
|
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil and gas sales
|
|
$
|
52,894
|
|
|
$
|
19,558
|
|
$
|
|
|
|
$
|
72,452
|
|
Overhead and services income
|
|
|
514
|
|
|
|
|
|
|
(339
|
)(c)
|
|
|
175
|
|
|
|
|
|
|
|
Total revenues
|
|
|
53,408
|
|
|
|
19,558
|
|
|
(339
|
)
|
|
|
72,627
|
|
Expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating
|
|
|
3,889
|
|
|
|
1,868
|
|
|
|
|
|
|
5,757
|
|
Severance and production taxes
|
|
|
1,736
|
|
|
|
716
|
|
|
|
|
|
|
2,452
|
|
Exploration
|
|
|
1,640
|
|
|
|
|
|
|
|
|
|
|
1,640
|
|
Impairment of non-producing
properties
|
|
|
558
|
|
|
|
|
|
|
|
|
|
|
558
|
|
General and administrative
|
|
|
2,930
|
|
|
|
|
|
|
|
|
|
|
2,930
|
|
Accretion of discount on asset
retirement obligations
|
|
|
10
|
|
|
|
|
|
|
4
|
(f)
|
|
|
14
|
|
Depreciation, depletion and
amortization
|
|
|
14,541
|
|
|
|
|
|
|
7,514
|
(d)
|
|
|
22,055
|
|
|
|
|
|
|
|
Total expenses
|
|
|
25,304
|
|
|
|
2,584
|
|
|
7,518
|
|
|
|
35,406
|
|
|
|
|
|
|
|
Operating income
|
|
|
28,104
|
|
|
|
16,974
|
|
|
(7,857
|
)
|
|
|
37,221
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense, net
|
|
|
(3,814
|
)
|
|
|
|
|
|
|
|
|
|
(3,814
|
)
|
Change in fair value of commodity
derivatives
|
|
|
8,668
|
|
|
|
|
|
|
|
|
|
|
8,668
|
|
|
|
|
|
|
|
Total other income (expense)
|
|
|
4,854
|
|
|
|
|
|
|
|
|
|
|
4,854
|
|
|
|
|
|
|
|
Income before provision for income
taxes
|
|
|
32,958
|
|
|
|
16,974
|
|
|
(7,857
|
)
|
|
|
42,075
|
|
Provision for income taxes
|
|
|
11,756
|
|
|
|
|
|
|
3,373
|
(e)
|
|
|
15,129
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$
|
21,202
|
|
|
$
|
16,974
|
|
$
|
(11,230
|
)
|
|
$
|
26,946
|
|
|
|
|
|
|
|
Earnings per share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
7.04
|
|
|
|
|
|
|
|
|
|
$
|
5.78
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
$
|
6.84
|
|
|
|
|
|
|
|
|
|
$
|
5.67
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares
outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
3,012,414
|
|
|
|
|
|
|
1,650,608
|
(i)
|
|
|
4,663,022
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
3,101,180
|
|
|
|
|
|
|
1,650,608
|
(i)
|
|
|
4,751,788
|
|
|
See accompanying
notes.
40
Approach
Resources Inc.
Notes to unaudited combined pro forma
financial statements
The accompanying unaudited combined pro forma balance sheet at
March 31, 2007 assumes that the acquisition of the Neo
Canyon interest occurred as of March 31, 2007. The
unaudited combined pro forma statement of operations for the
year ended December 31, 2006 and the three months ended
March 31, 2007 assume the acquisition occurred as of
January 1, 2006 and January 1, 2007, respectively. The
following adjustments have been made to the accompanying pro
forma statements:
|
|
(a)
|
To record the acquisition of the Neo Canyon interest for
$69.4 million by the issuance of 1,413,081 shares of
Approach Resources Inc. common stock at March 31, 2007, and
the assumption of related asset retirement obligations at that
date. The issuance of 1,413,081 shares of common stock is
subject to adjustment based on a potential split of Approach
Resources Inc. common stock. The following is a summary of the
purchase price and its allocation (in thousands):
|
|
|
|
|
|
Purchase price:
|
|
|
|
Issuance of 1,413,081 shares
of Approach Resources Inc. common stock valued at $49.11 per
share
|
|
$
|
69,400
|
Plus: assumption of asset
retirement obligations
|
|
|
63
|
|
|
|
|
Total purchase price
|
|
$
|
69,463
|
|
|
|
|
Allocation:
|
|
|
|
Leasehold costs
|
|
$
|
750
|
Lease and well equipment
|
|
|
18,572
|
Intangible drilling costs
|
|
|
50,141
|
|
|
|
|
Total
|
|
$
|
69,463
|
|
|
|
|
(b)
|
To record the issuance of 329,719 shares of Approach
Resources Inc. common stock in exchange for 150,000 shares
of Approach Oil & Gas Inc. common stock.
|
|
(c)
|
To eliminate operating overhead recoveries by Approach from Neo
Canyon.
|
|
(d)
|
To adjust annual depletion and depreciation expense for the Neo
Canyon interest based on the acquisition price valued at
$69.5 million. The pro forma adjustment is based on the
production and reserve information summarized under Pro Forma
Supplementary Financial Information for Oil and Gas Producing
Activities (Unaudited) below.
|
|
(e)
|
To record additional provision for income tax related to the
acquisition of the Neo Canyon interest based on an
effective income tax rate of 34.66%.
|
|
(f)
|
To record additional accretion of discount on asset retirement
obligations related to the obligations assumed in the
acquisition of the Neo Canyon interest. The pro forma
amount for the three months ended March 31, 2007 is
inconsequential.
|
41
|
|
(g)
|
To adjust the weighted average shares outstanding for the
issuance of shares to Neo Canyon in exchange for the
interest acquired as well as shares issued to stockholders of
Approach Oil & Gas Inc. The pro forma adjustment
comprises the following:
|
|
|
|
|
|
|
Issuance of shares for the
acquisition of Neo Canyon interest
|
|
|
1,413,081
|
|
Issuance of shares for the
Approach Oil & Gas Inc. combination
|
|
|
329,719
|
|
Purchase of Approach
Oil & Gas Inc. common shares
|
|
|
(150,000
|
)
|
|
|
|
|
|
Total
|
|
|
1,592,800
|
|
|
|
|
|
(h)
|
To adjust the weighted average shares outstanding for the items
discussed in (f) and to record the dilutive impact of
restricted shares and stock options outstanding that would have
been anti-dilutive based on Approach Resources Inc. historical
amounts. The pro forma adjustment comprises the following:
|
|
|
|
|
|
|
Issuance of shares for the
acquisition of Neo Canyon interest
|
|
|
1,413,081
|
|
Issuance of shares for the
Approach Oil & Gas Inc. combination
|
|
|
329,719
|
|
Purchase of Approach
Oil & Gas Inc. common shares
|
|
|
(150,000
|
)
|
Dilutive impact of non-vested
restricted stock grants
|
|
|
21,250
|
|
Dilutive impact of stock options
outstanding, treasury method
|
|
|
91,980
|
|
|
|
|
|
|
Total
|
|
|
1,706,030
|
|
|
|
|
|
(i)
|
To adjust the weighted average shares outstanding for the
issuance of shares to Neo Canyon in exchange for the
interest acquired as well as shares issued to stockholders of
Approach Oil & Gas Inc. The pro forma adjustment
comprises the following:
|
|
|
|
|
|
|
Issuance of shares for the
acquisition of Neo Canyon interest
|
|
|
1,413,081
|
|
Issuance of shares for the
Approach Oil & Gas Inc. combination
|
|
|
329,719
|
|
Purchase of Approach
Oil & Gas Inc. common shares (represents the weighted
average shares outstanding of Approach Oil & Gas Inc.
for the year ended December 31, 2006)
|
|
|
(92,192
|
)
|
|
|
|
|
|
Total
|
|
|
1,650,608
|
|
|
|
42
Pro forma
supplementary financial information for oil and gas producing
activities (unaudited)
The following tables present certain unaudited pro forma
information concerning Approachs proved oil and gas
reserves giving effect to the acquisition of the Neo Canyon
interest as if it had occurred on January 1, 2006. There
are numerous uncertainties inherent in estimating the quantities
of proved reserves and projecting future rates of production and
timing of development expenditures. The following reserve data
represent estimates only and should not be construed as being
exact. The proved oil and gas reserve information for Approach
and Neo Canyon is as of December 31, 2006 and reflects
prices and costs as of those dates.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Approach
Resources Inc.
|
|
|
Neo Canyon
|
|
|
Combined
|
|
|
|
combined
historical
|
|
|
historical
|
|
|
pro forma
|
|
ReservesCrude
oil & natural gas liquids (MBbls)
|
|
amounts
|
|
|
amounts
|
|
|
amounts
|
|
|
|
|
Reserves at beginning of period
|
|
|
1,086
|
|
|
|
467
|
|
|
|
1,553
|
|
Extensions and discoveries
|
|
|
339
|
|
|
|
61
|
|
|
|
400
|
|
Revisions of previous estimates
|
|
|
(226
|
)
|
|
|
(105
|
)
|
|
|
(331
|
)
|
Production
|
|
|
(77
|
)
|
|
|
(32
|
)
|
|
|
(109
|
)
|
|
|
|
|
|
|
Reserves at end of period
|
|
|
1,122
|
|
|
|
391
|
|
|
|
1,513
|
|
|
|
|
|
|
|
Proved developed producing
reserves at end of period
|
|
|
496
|
|
|
|
170
|
|
|
|
666
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Approach
Resources Inc.
|
|
|
Neo Canyon
|
|
|
Combined
|
|
|
|
combined
historical
|
|
|
historical
|
|
|
pro forma
|
|
ReservesNatural
gas (MMcf):
|
|
amounts
|
|
|
amounts
|
|
|
amounts
|
|
|
|
|
Reserves at beginning of period
|
|
|
102,405
|
|
|
|
42,899
|
|
|
|
145,304
|
|
Extensions and discoveries
|
|
|
15,655
|
|
|
|
6,421
|
|
|
|
22,076
|
|
Revisions of previous estimates
|
|
|
(13,121
|
)
|
|
|
(5,526
|
)
|
|
|
(18,647
|
)
|
Production
|
|
|
(6,282
|
)
|
|
|
(2,645
|
)
|
|
|
(8,927
|
)
|
|
|
|
|
|
|
Reserves at end of period
|
|
|
98,657
|
|
|
|
41,149
|
|
|
|
139,806
|
|
|
|
|
|
|
|
Proved developed producing
reserves at end of period
|
|
|
51,004
|
|
|
|
21,400
|
|
|
|
72,404
|
|
|
|
43
Standardized
measure of discounted future cash flows (in
thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Approach
Resources Inc.
|
|
|
Neo Canyon
|
|
|
Combined
|
|
|
|
combined
historical
|
|
|
historical
|
|
|
pro forma
|
|
|
|
amounts
|
|
|
amounts
|
|
|
amounts
|
|
|
|
Future cash inflows
|
|
$
|
709,184
|
|
|
$
|
292,399
|
|
|
$
|
1,001,583
|
|
Future production costs
|
|
|
(198,023
|
)
|
|
|
(81,784
|
)
|
|
|
(279,807
|
)
|
Future development costs
|
|
|
(108,451
|
)
|
|
|
(45,957
|
)
|
|
|
(154,408
|
)
|
Future income taxes
|
|
|
(109,784
|
)
|
|
|
(1,647
|
)
|
|
|
(111,431
|
)
|
|
|
|
|
|
|
Future net cash flows
|
|
|
292,926
|
|
|
|
163,011
|
|
|
|
455,937
|
|
10% annual discount
|
|
|
(215,049
|
)
|
|
|
(112,306
|
)
|
|
|
(327,355
|
)
|
|
|
|
|
|
|
Standardized measure of discounted
future net cash flows
|
|
$
|
77,877
|
|
|
$
|
50,705
|
|
|
$
|
128,582
|
|
|
|
Changes in
standardized measure of discounted future cash flows
(in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Approach
Resources Inc.
|
|
|
Neo Canyon
|
|
|
Combined
|
|
|
|
combined
historical
|
|
|
historical
|
|
|
pro forma
|
|
|
|
amounts
|
|
|
amounts
|
|
|
amounts
|
|
|
|
Balance at beginning of period
|
|
$
|
146,439
|
|
|
$
|
109,078
|
|
|
$
|
255,517
|
|
Net changes in prices and
production costs
|
|
|
(106,246
|
)
|
|
|
(56,734
|
)
|
|
|
(162,980
|
)
|
Net changes in future development
costs
|
|
|
(43,229
|
)
|
|
|
(9,707
|
)
|
|
|
(52,936
|
)
|
Sales of oil and gas produced, net
|
|
|
(40,852
|
)
|
|
|
(16,974
|
)
|
|
|
(57,826
|
)
|
Net change due to extensions,
discoveries and improved recovery techniques
|
|
|
28,418
|
|
|
|
10,265
|
|
|
|
38,683
|
|
Revisions of previous quantity
estimates
|
|
|
(22,112
|
)
|
|
|
(9,314
|
)
|
|
|
(31,426
|
)
|
Previously estimated development
costs incurred
|
|
|
52,108
|
|
|
|
22,332
|
|
|
|
74,440
|
|
Net change in income taxes
|
|
|
52,303
|
|
|
|
(726
|
)
|
|
|
51,577
|
|
Accretion of discount
|
|
|
15,546
|
|
|
|
6,136
|
|
|
|
21,682
|
|
Other
|
|
|
(4,498
|
)
|
|
|
(3,651
|
)
|
|
|
(8,149
|
)
|
|
|
|
|
|
|
Balance at end of period
|
|
$
|
77,877
|
|
|
$
|
50,705
|
|
|
$
|
128,582
|
|
|
|
44
Selected
historical combined financial data
The following table sets forth our selected historical combined
financial data as of the dates and for the periods shown. Our
operations are currently conducted in two separate entities
under common control, Approach Resources Inc. and Approach
Oil & Gas Inc. Pursuant to a contribution agreement,
the operations of Approach Oil & Gas Inc. will be
combined under Approach Resources Inc., and we will also acquire
the Neo Canyon interest immediately prior to the closing of this
offering. The historical financial data for the year ended
December 31, 2002 has been derived from our unaudited
financial statements, which are not included in this prospectus.
The historical financial data for the year ended
December 31, 2003 have been derived from our audited
financial statements, which are not included in this prospectus.
The historical combined financial data for the years ended
December 31, 2004, 2005 and 2006 and for the three months
ended March 31, 2006 and 2007 have been derived from the
combined financial statements of Approach Resources Inc. and
Approach Oil & Gas Inc. included in this prospectus.
The following information should be read in conjunction with
Capitalization, Managements discussion
and analysis of financial condition and results of
operations and the historical combined and combined pro
forma financial statements included in this prospectus.
45
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 13,
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three months
|
|
|
|
2002 to
|
|
|
Year ended
December 31,
|
|
|
ended
March 31,
|
|
|
|
December 31,
|
|
|
|
|
|
2004
|
|
|
2005
|
|
|
2006
|
|
|
2006
|
|
|
2007
|
|
|
|
2002
|
|
|
2003
|
|
|
combined
|
|
|
combined
|
|
|
combined
|
|
|
combined
|
|
|
combined
|
|
(in thousands,
except per share data)
|
|
historical
|
|
|
historical
|
|
|
historical
|
|
|
historical
|
|
|
historical
|
|
|
historical
|
|
|
historical
|
|
|
|
|
|
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(unaudited)
|
|
|
(unaudited)
|
|
|
Statement of operations
data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil and gas sales
|
|
$
|
|
|
|
$
|
|
|
|
$
|
5,682
|
|
|
$
|
40,339
|
|
|
$
|
52,894
|
|
|
$
|
15,680
|
|
|
$
|
11,547
|
|
Overhead and services income
|
|
|
133
|
|
|
|
|
|
|
|
131
|
|
|
|
408
|
|
|
|
514
|
|
|
|
122
|
|
|
|
133
|
|
|
|
|
|
|
|
Total revenues
|
|
|
133
|
|
|
|
|
|
|
|
5,813
|
|
|
|
40,747
|
|
|
|
53,408
|
|
|
|
15,802
|
|
|
|
11,680
|
|
Expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating expense
|
|
|
|
|
|
|
|
|
|
|
179
|
|
|
|
2,910
|
|
|
|
3,889
|
|
|
|
973
|
|
|
|
979
|
|
Severance and production taxes
|
|
|
|
|
|
|
|
|
|
|
407
|
|
|
|
1,975
|
|
|
|
1,736
|
|
|
|
380
|
|
|
|
375
|
|
Exploration
|
|
|
|
|
|
|
442
|
|
|
|
2,396
|
|
|
|
733
|
|
|
|
1,640
|
|
|
|
196
|
|
|
|
623
|
|
Impairment of non-producing
properties
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
558
|
|
|
|
|
|
|
|
|
|
General and administrative
|
|
|
539
|
|
|
|
1,535
|
|
|
|
2,074
|
|
|
|
3,067
|
|
|
|
2,930
|
|
|
|
750
|
|
|
|
1,646
|
|
Accretion of discount on asset
retirement obligations
|
|
|
|
|
|
|
|
|
|
|
1
|
|
|
|
5
|
|
|
|
10
|
|
|
|
|
|
|
|
3
|
|
Depletion, depreciation and
amortization
|
|
|
2
|
|
|
|
9
|
|
|
|
1,223
|
|
|
|
8,006
|
|
|
|
14,541
|
|
|
|
3,281
|
|
|
|
3,088
|
|
|
|
|
|
|
|
Total expenses
|
|
|
541
|
|
|
|
1,986
|
|
|
|
6,280
|
|
|
|
16,696
|
|
|
|
25,304
|
|
|
|
5,580
|
|
|
|
6,714
|
|
|
|
|
|
|
|
Operating income (loss)
|
|
|
(408
|
)
|
|
|
(1,986
|
)
|
|
|
(467
|
)
|
|
|
24,051
|
|
|
|
28,104
|
|
|
|
10,222
|
|
|
|
4,966
|
|
Other:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income (expense), net
|
|
|
(1
|
)
|
|
|
59
|
|
|
|
201
|
|
|
|
(802
|
)
|
|
|
(3,814
|
)
|
|
|
(725
|
)
|
|
|
(956
|
)
|
Change in fair value of commodity
derivatives
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(4,163
|
)
|
|
|
8,668
|
|
|
|
6,192
|
|
|
|
(4,626
|
)
|
|
|
|
|
|
|
Income (loss) before provision for
income taxes
|
|
|
(409
|
)
|
|
|
(1,927
|
)
|
|
|
(266
|
)
|
|
|
19,086
|
|
|
|
32,958
|
|
|
|
15,689
|
|
|
|
(616
|
)
|
Provision (benefit) for income taxes
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
7,028
|
|
|
|
11,756
|
|
|
|
5,280
|
|
|
|
(35
|
)
|
|
|
|
|
|
|
Net income (loss)
|
|
$
|
(409
|
)
|
|
$
|
(1,927
|
)
|
|
$
|
(266
|
)
|
|
$
|
12,058
|
|
|
$
|
21,202
|
|
|
$
|
10,409
|
|
|
$
|
(581
|
)
|
|
|
|
|
|
|
Earnings (loss) per share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
|
|
|
$
|
(3.44
|
)
|
|
$
|
(0.14
|
)
|
|
$
|
4.03
|
|
|
$
|
7.04
|
|
|
$
|
3.49
|
|
|
$
|
(0.19
|
)
|
|
|
|
|
|
|
Diluted
|
|
$
|
|
|
|
$
|
(3.44
|
)
|
|
$
|
(0.14
|
)
|
|
$
|
4.03
|
|
|
$
|
6.84
|
|
|
$
|
3.39
|
|
|
$
|
(0.19
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Statement of cash flows
data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided (used) by:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating activities
|
|
$
|
(258
|
)
|
|
$
|
(2,391
|
)
|
|
$
|
4,527
|
|
|
$
|
40,304
|
|
|
$
|
34,110
|
|
|
$
|
12,616
|
|
|
$
|
5,687
|
|
Investing activities
|
|
|
(3
|
)
|
|
|
(15
|
)
|
|
|
(26,859
|
)
|
|
|
(71,939
|
)
|
|
|
(59,189
|
)
|
|
|
(24,578
|
)
|
|
|
(9,717
|
)
|
Financing activities
|
|
|
282
|
|
|
|
4,898
|
|
|
|
22,474
|
|
|
|
32,199
|
|
|
|
26,771
|
|
|
|
9,918
|
|
|
|
4,493
|
|
Other financial data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDAX(1)
|
|
|
(406
|
)
|
|
|
(1,535
|
)
|
|
|
3,152
|
|
|
|
32,791
|
|
|
|
44,877
|
|
|
|
13,699
|
|
|
|
8,677
|
|
Capital expenditures
|
|
|
3
|
|
|
|
15
|
|
|
|
25,313
|
|
|
|
73,485
|
|
|
|
59,189
|
|
|
|
24,578
|
|
|
|
9,717
|
|
|
|
|
|
|
(1)
|
|
See Reconciliation of
non-GAAP financial measures below for additional
information.
|
46
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As of December
31,
|
|
As of
March 31,
|
|
|
|
|
|
|
|
2004
|
|
2005
|
|
2006
|
|
2006
|
|
2007
|
|
|
2002
|
|
|
2003
|
|
combined
|
|
combined
|
|
combined
|
|
combined
|
|
combined
|
(in
thousands)
|
|
historical
|
|
|
historical
|
|
historical
|
|
historical
|
|
historical
|
|
historical
|
|
historical
|
|
|
|
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
(unaudited)
|
|
(unaudited)
|
|
Balance sheet data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash
|
|
$
|
21
|
|
|
$
|
2,513
|
|
$
|
2,656
|
|
$
|
3,219
|
|
$
|
4,911
|
|
$
|
1,175
|
|
$
|
5,374
|
Other current assets
|
|
|
|
|
|
|
410
|
|
|
6,458
|
|
|
16,305
|
|
|
13,200
|
|
|
16,660
|
|
|
6,776
|
Property and equipment, net,
successful efforts method
|
|
|
92
|
|
|
|
35
|
|
|
24,223
|
|
|
88,803
|
|
|
132,112
|
|
|
109,904
|
|
|
138,123
|
Other assets
|
|
|
29
|
|
|
|
|
|
|
1,565
|
|
|
89
|
|
|
86
|
|
|
101
|
|
|
119
|
|
|
|
|
|
|
Total assets
|
|
$
|
142
|
|
|
$
|
2,958
|
|
$
|
34,902
|
|
$
|
108,416
|
|
$
|
150,309
|
|
$
|
127,840
|
|
$
|
150,392
|
|
|
|
|
|
|
Current liabilities
|
|
$
|
499
|
|
|
$
|
86
|
|
$
|
9,827
|
|
$
|
32,746
|
|
$
|
15,421
|
|
$
|
26,811
|
|
$
|
11,564
|
Long-term debt
|
|
|
|
|
|
|
|
|
|
100
|
|
|
29,425
|
|
|
47,619
|
|
|
40,660
|
|
|
52,169
|
Other long-term liabilities
|
|
|
|
|
|
|
|
|
|
99
|
|
|
6,555
|
|
|
17,697
|
|
|
11,562
|
|
|
17,669
|
Stockholders equity (deficit)
|
|
|
(357
|
)
|
|
|
2,872
|
|
|
24,876
|
|
|
39,690
|
|
|
69,572
|
|
|
48,807
|
|
|
68,990
|
|
|
|
|
|
|
Total liabilities and
stockholders equity
|
|
$
|
142
|
|
|
$
|
2,958
|
|
$
|
34,902
|
|
$
|
108,416
|
|
$
|
150,309
|
|
$
|
127,840
|
|
$
|
150,392
|
|
|
Reconciliation of
non-GAAP financial measures
The following table shows our reconciliation of our
PV-10
to our
standardized measure of discounted future net cash flows (the
most directly comparable measure calculated and presented in
accordance with generally accepted accounting principles, or
GAAP).
PV-10
is our estimate of the present value of future net revenues from
estimated proved gas reserves after deducting estimated
production and ad valorem taxes, future capital costs and
operating expenses, but before deducting any estimates of future
income taxes. The estimated future net revenues are discounted
at an annual rate of 10% to determine their present
value. We believe
PV-10
to be
an important measure for evaluating the relative significance of
our gas and oil properties and that the presentation of the
non-GAAP financial measure of
PV-10
provides useful information to investors because it is widely
used by professional analysts and sophisticated investors in
evaluating gas and oil companies. Because there are many unique
factors that can impact an individual company when estimating
the amount of future income taxes to be paid, we believe the use
of a pre-tax measure is valuable for evaluating our company. We
believe that most other companies in the oil and gas industry
calculate
PV-10
on the
same basis.
47
PV-10
should
not be considered as an alternative to the standardized measure
of discounted future net cash flows as computed under GAAP.
|
|
|
|
|
|
|
|
|
As of
|
|
|
|
December 31,
|
|
(in
thousands)
|
|
2006
|
|
|
|
|
PV-10
|
|
$
|
179,865
|
|
Less: Undiscounted income taxes
|
|
|
(111,431
|
)
|
Plus: 10% discount factor
|
|
|
60,148
|
|
|
|
|
|
|
Discounted income taxes
|
|
|
(51,283
|
)
|
|
|
|
|
|
Standardized measure of discounted
future net cash flows
|
|
$
|
128,582
|
|
|
|
The following table reconciles our net income to EBITDAX.
EBITDAX is defined as net income or loss excluding income tax,
non-cash compensation, changes in fair value of commodity
derivatives, exploration and other impairment costs,
depreciation, depletion and amortization and interest expense.
Although EBITDAX is not calculated in accordance with GAAP,
management believes that it is a widely accepted financial
indicator that provides additional information about our
profitability, ability to meet our future requirements for debt
service, capital expenditures and working capital. EBITDAX
should not be considered in isolation or as a substitute for net
income, operating income, net cash provided by operating
activities or any other measure of financial performance
presented in accordance with GAAP.
While we have disclosed our EBITDAX to permit a more complete
comparative analysis of our operating performance and debt
servicing ability relative to other companies, investors should
be cautioned that EBITDAX as reported by us may not be
comparable in all instances to EBITDAX as reported by other
companies. In addition, EBITDAX amounts may not be fully
available for managements discretionary use, due to the
requirements to conserve funds for capital expenditures, debt
service or other commitments.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 13,
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three months
|
|
|
Pro
forma
|
|
|
2002 to
|
|
|
Year ended
December 31,
|
|
|
ended
March 31,
|
|
|
|
|
|
Three months
|
|
|
December 31,
|
|
|
|
|
|
2004
|
|
|
2005
|
|
2006
|
|
|
2006
|
|
|
2007
|
|
|
Year ended
|
|
|
ended
|
|
|
2002
|
|
|
2003
|
|
|
combined
|
|
|
combined
|
|
combined
|
|
|
combined
|
|
|
combined
|
|
|
December 31,
|
|
|
March 31,
|
(in
thousands)
|
|
historical
|
|
|
historical
|
|
|
historical
|
|
|
historical
|
|
historical
|
|
|
historical
|
|
|
historical
|
|
|
2006
|
|
|
2007
|
|
|
|
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(unaudited)
|
|
|
(unaudited)
|
|
|
(unaudited)
|
|
|
(unaudited)
|
|
Net income (loss)
|
|
$
|
(409
|
)
|
|
$
|
(1,927
|
)
|
|
$
|
(266
|
)
|
|
$
|
12,058
|
|
$
|
21,202
|
|
|
$
|
10,409
|
|
|
$
|
(581
|
)
|
|
$
|
26,946
|
|
|
$
|
375
|
Income taxes
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
7,028
|
|
|
11,756
|
|
|
|
5,280
|
|
|
|
(35
|
)
|
|
|
15,129
|
|
|
|
473
|
Non-cash compensation
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
34
|
|
|
|
|
|
|
|
|
|
|
|
34
|
|
|
|
|
Change in fair value of commodity
derivatives
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4,163
|
|
|
(8,668
|
)
|
|
|
(6,192
|
)
|
|
|
4,626
|
|
|
|
(8,668
|
)
|
|
|
4,626
|
Exploration and impairment costs
|
|
|
|
|
|
|
442
|
|
|
|
2,396
|
|
|
|
734
|
|
|
2,198
|
|
|
|
196
|
|
|
|
623
|
|
|
|
2,198
|
|
|
|
623
|
Depreciation, depletion and
amortization
|
|
|
2
|
|
|
|
9
|
|
|
|
1,223
|
|
|
|
8,006
|
|
|
14,541
|
|
|
|
3,281
|
|
|
|
3,088
|
|
|
|
22,055
|
|
|
|
4,737
|
Interest expense (income)
|
|
|
1
|
|
|
|
(59
|
)
|
|
|
(201
|
)
|
|
|
802
|
|
|
3,814
|
|
|
|
725
|
|
|
|
956
|
|
|
|
3,814
|
|
|
|
956
|
|
|
|
|
|
|
EBITDAX
|
|
$
|
(406
|
)
|
|
$
|
(1,535
|
)
|
|
$
|
3,152
|
|
|
$
|
32,791
|
|
$
|
44,877
|
|
|
$
|
13,699
|
|
|
$
|
8,677
|
|
|
$
|
61,508
|
|
|
$
|
11,790
|
|
|
48
Managements
discussion and analysis of financial
condition and results of operations
The following discussion is intended to assist in understanding
our results of operations and our financial condition. Our
combined financial statements and the accompanying notes
included elsewhere in this prospectus contain additional
information that should be referred to when reviewing this
material. Statements in this discussion may be forward-looking.
These forward-looking statements involve risks and
uncertainties, which could cause actual results to differ from
those expressed.
Overview
We are an independent energy company engaged in the exploration,
development, exploitation, production and acquisition of
unconventional oil and gas properties onshore in the United
States. We are focusing our growth efforts primarily on finding
and developing natural gas reserves in known tight gas sands and
shale areas and have assembled leasehold interests aggregating
approximately 231,000 gross (177,000 net) acres. We
expect to leverage our management teams proven track
record of finding and exploiting unconventional reservoirs
through application of advanced completion, fracturing and
drilling techniques. As the operator of substantially all of our
proved reserves, we have a high degree of control over capital
expenditures and other operating matters.
We currently operate in three areas: West Texas (Wolfcamp,
Canyon Sands and Ellenburger), Western Kentucky (New Albany
Shale) and Northern New Mexico (Mancos Shale). As of
December 31, 2006, all of our proved reserves and
production were located in our West Texas operating area and
substantially all of those reserves and production were located
in the Ozona Northeast field.
Our financial results depend upon many factors, particularly the
price of oil and gas. Commodity prices are affected by changes
in market demand, which is impacted by overall economic
activity, weather, pipeline capacity constraints, inventory
storage levels, gas price differentials and other factors. As a
result, we cannot accurately predict future oil and gas prices,
and therefore, we cannot determine what effect increases or
decreases will have on our capital program, production volumes
and future revenues. In addition to production volumes and
commodity prices, finding and developing sufficient amounts of
oil and gas reserves at economical costs are critical to our
long-term success. Future finding and development costs are
subject to changes in the industry, including the costs of
acquiring, drilling and completing our projects.
Higher oil and gas prices have led to higher demand for drilling
rigs, operating personnel and field supplies and services and
have caused increases in the costs of those goods and services.
To date, the higher sales prices have more than offset the
higher drilling and operating costs. Given the inherent
volatility of gas prices, which are influenced by many factors
beyond our control, we plan our activities and budget based on
conservative sales price assumptions, which generally are lower
than the average sales prices received. We focus our efforts on
increasing gas reserves and production while controlling costs
at a level that is appropriate for long-term operations. Our
future cash flow from operations will depend on our ability to
manage our overall cost structure.
Like all oil and gas production companies, we face the challenge
of natural production declines. Oil and gas production from a
given well naturally decreases over time. Additionally, our
49
reserves have a rapid initial decline. We attempt to overcome
this natural decline by drilling to develop and identify
additional reserves and by acquisitions. Our future growth will
depend upon our ability to continue to add oil and gas reserves
in excess of production at a reasonable cost. We will maintain
our focus on the costs of adding reserves through drilling and
acquisitions as well as the costs necessary to produce such
reserves.
We also face the challenge of financing future acquisitions. We
plan to use the proceeds of this offering to repay the
$ million of outstanding
borrowings under our revolving credit facility plus accrued
interest. At that point, we believe we will have adequate unused
borrowing capacity under our revolving credit facility for
possible acquisitions, temporary working capital needs and any
expansion of our drilling program. Funding for future
acquisitions also may require additional sources of financing,
which may not be available.
Our operations are currently conducted in two separate entities
under common control, Approach Resources Inc. and Approach
Oil & Gas Inc. Pursuant to a contribution agreement,
the operations of these two entities will be combined under
Approach Resources Inc., and we will also acquire the Neo Canyon
interest immediately before the closing of this offering.
Critical
accounting policies and estimates
The discussion and analysis of our financial condition and
results of operations are based upon our combined financial
statements, which have been prepared in accordance with
accounting policies generally accepted in the United States. The
preparation of our combined financial statements requires us to
make estimates and assumptions that affect our reported results
of operations and the amount of reported assets, liabilities and
proved oil and gas reserves. Some accounting policies involve
judgments and uncertainties to such an extent that there is
reasonable likelihood that materially different amounts could
have been reported under different conditions, or if different
assumptions had been used. Actual results may differ from the
estimates and assumptions used in the preparation of our
combined financial statements. Described below are the most
significant policies we apply in preparing our combined
financial statements, some of which are subject to alternative
treatments under GAAP. We also describe the most significant
estimates and assumptions we make in applying these policies.
See notes to the financial statements under the heading
Summary of significant accounting policies for
additional accounting policies and estimates by management.
Oil and gas
activities
Accounting for oil and gas activities is subject to special,
unique rules. We use the successful efforts method for
accounting for our oil and gas activities. The significant
principles for this method are:
|
|
|
geological and geophysical evaluation costs are expensed as
incurred;
|
|
|
dry holes for exploratory wells are expensed, and dry holes for
developmental wells are capitalized; and
|
|
|
impairments of properties, if any, are based on the evaluation
of the carrying value of properties against their fair value
based upon pools of properties grouped by geographical and
geological conformity.
|
50
|
|
|
Our engineering estimates of proved oil and gas reserves
directly impact financial accounting estimates including
depletion, depreciation and amortization expense, evaluation of
impairment of properties and the calculation of plugging and
abandonment liabilities. Proved oil and gas reserves are the
estimated quantities of oil and gas that geological and
engineering data demonstrate with reasonable certainty to be
recoverable in future years from known reservoirs under
period-end economic and operating conditions. The process of
estimating quantities of proved reserves is very complex,
requiring significant subjective decisions in the evaluation of
all geological, engineering and economic data for each
reservoir. The data for any reservoir may change substantially
over time as a result of changing results from operational
activity and results. Changes in commodity prices, operation
costs and techniques may also affect the overall evaluation of
reservoirs. A hypothetical 10% decline in our December 31,
2006 proved reserves volumes would have resulted in
approximately $1.4 million of additional depletion expense
for the year ended December 31, 2006.
|
Our estimated proved reserves as of December 31, 2006 were
prepared by DeGolyer and MacNaughton.
Derivative
instruments and hedging activities
All derivative instruments are recorded on the balance sheet at
fair value. Changes in the derivatives fair value are
currently recognized in the statement of operations unless
specific hedge accounting criteria are met. For qualifying
cash-flow hedges, the gain or loss on the derivative is deferred
in accumulated other comprehensive income (loss) to the extent
the hedge is effective. The ineffective portion of the hedge is
recognized immediately in the statement of operations. Gains and
losses on hedging instruments included in cumulative other
comprehensive income (loss) are reclassified to oil and gas
sales revenue in the period that the related production is
delivered. Derivative contracts that do not qualify for hedge
accounting treatment are recorded as derivative assets and
liabilities at fair value in the balance sheet, and the
associated unrealized gains and losses are recorded as current
income or expense in the statement of operations.
Historically, we have not designated our derivative instruments
as cash-flow hedges. We record our open derivative instruments
at fair value on our combined balance sheets as either
unrealized gains or losses on commodity derivatives. We record
changes in such fair value in earnings on our combined
statements of operations under the caption entitled change
in fair value of commodity derivatives.
Although we have not designated our derivative instruments as
cash-flow hedges, we use those instruments to reduce our
exposure to fluctuations in commodity prices related to our oil
and gas production. Accordingly, we record realized gains and
losses under those instruments in oil and gas sales revenues on
our combined statements of operations. For the years ended
December 31, 2005 and 2006, we recognized an unrealized
loss of $4,163,098 and an unrealized gain of $8,668,095 from
changes in the fair values of commodity derivatives,
respectively. A 10% increase in the NYMEX floating prices would
have resulted in a $2.0 million decrease in the
December 31, 2006 fair value recorded on our balance sheet,
and a corresponding increase to loss on commodity derivatives in
our statement of operations.
51
Recent accounting
pronouncements
On December 16, 2004, the Financial Accounting Standards
Board, or FASB, published Statement of Financial Accounting
Standards No. 123 (Revised 2004),
Share Based
Payment
, or SFAS 123(R). SFAS 123(R) requires
compensation cost related to share based payment transactions to
be recognized in the financial statements. Share based payment
transactions within the scope of SFAS 123(R) include stock
options, restricted stock plans, performance based awards, stock
appreciation rights and employee share purchase plans. The
provisions of SFAS 123(R) were effective for us as of the
first annual reporting period beginning after December 15,
2005. Accordingly, we implemented the revised standard on
January 1, 2006.
In March 2005, FASB issued FASB Interpretation No. 47,
Accounting for Conditional Asset Retirement Obligations
,
or FIN 47. FIN 47 clarifies the definition and
treatment of conditional asset retirement obligations as
discussed in FASB Statement No. 143,
Accounting for
Asset Retirement Obligations
. A conditional asset retirement
obligation is defined as an asset retirement activity in which
the timing
and/or
method of settlement are dependent on future events that may be
outside our control. FIN 47 states that we must record
a liability when incurred for conditional asset retirement
obligations if the fair value of the obligation is reasonably
estimable. This interpretation is intended to provide more
information about long-lived assets, future cash outflows for
these obligations and more consistent recognition of these
liabilities. FIN 47 is effective for fiscal years ending
after December 15, 2005. We do not believe that our
financial position, results of operations or cash flows will be
impacted by FIN 47.
In June 2006, the FASB issued Interpretation No. 48,
Accounting for Uncertainty in Income Taxesan
Interpretation of FASB Statement No. 109
, or
FIN 48. FIN 48 clarifies the accounting for
uncertainty in income taxes recognized in a companys
financial statements and prescribes a recognition threshold and
measurement attribute for the financial statement recognition
and measurement of a tax position taken or expected to be taken
in a tax return. We adopted FIN 48 on January 1, 2007
and it did not have a material impact on our financial
statements.
In September 2006, the FASB issued FAS No. 157,
Fair Value Measurements
, or FAS 157. FAS 157
defines fair value to measure assets and liabilities,
establishes a framework for measuring fair value and requires
additional disclosures about the use of fair value. FAS 157
is applicable whenever another accounting pronouncement requires
or permits assets and liabilities to be measured at fair value.
FAS 157 does not expand or require any new fair value
measures. FAS 157 is effective for our fiscal year
beginning January 1, 2008. We are currently evaluating the
impact that the adoption of FAS 157 will have on our
financial position or results of operations.
Effects of
inflation
Inflation in the United States has been relatively low in recent
years and did not have a material impact on our results of
operations for the years ended December 31, 2004, 2005 or
2006. Although the impact of inflation has been insignificant in
recent years, it is still a factor in the United States economy
and may increase the cost to acquire or replace property, plant
and equipment. It may also increase the cost of labor or
supplies. To the extent permitted by competition, regulation and
our existing agreements, we have and will continue to pass along
increased costs to our customers in the form of higher prices.
52
Stock based and
other compensation
Our 2007 Stock Incentive Plan allows grants of stock and options
to management and key employees. Granting of awards may increase
our general and administrative expenses subject to the size and
timing of the grants.
Public company
expenses
We believe that our general and administrative expenses will
increase in connection with the completion of this offering as a
result of us operating as a public company. This increase will
consist of legal and accounting fees and additional expenses
associated with compliance with the Sarbanes Oxley Act of 2002
and other regulations. We anticipate that our ongoing general
and administrative expenses also will increase as a result of
being a publicly traded company. This increase will be due
primarily to the cost of accounting support services, filing
annual and quarterly reports with the SEC, investor relations,
directors fees, directors and officers
insurance and registrar and transfer agent fees. As a result, we
believe that our general and administrative expenses for future
periods will increase significantly. Our consolidated financial
statements following the completion of this offering will
reflect the impact of these increased expenses and affect the
comparability of our financial statements with periods before
the completion of this offering.
Results of
operations
Three months
ended March 31, 2006 and 2007
|
|
|
|
|
|
|
|
|
|
Three months
ended
|
|
|
March 31,
|
|
|
2006
|
|
2007
|
|
|
Net production (MMcfe)
|
|
|
1,837
|
|
|
1,357
|
Average sales prices (per Mcfe)
(before hedging)
|
|
$
|
7.76
|
|
$
|
6.92
|
Costs and expenses (in thousands):
|
|
|
|
|
|
|
Lease operating expenses
|
|
$
|
973
|
|
$
|
980
|
Production taxes
|
|
|
380
|
|
|
375
|
Depreciation, depletion and
amortization
|
|
|
3,281
|
|
|
3,088
|
General and administrative
|
|
|
750
|
|
|
1,646
|
|
|
Oil and gas sales.
Oil and gas sales decreased
$4.1 million, or 26.4%, for the three months ended
March 31, 2007 to $11.6 million from
$15.7 million for the three months ended March 31,
2006. The decrease in gas sales principally resulted from the
natural decline in production of our tight gas sands in the
Northeast Ozona field. Further, we had four rigs drilling in the
second half of 2005 and the first half of 2006, which
dramatically increased production in the first quarter of 2006
from new wells placed in production compared to the use of only
one rig in the latter part of 2006 and early 2007. Additionally,
the average price for gas including the effects of hedging
increased slightly by $0.11 per Mcfe, or 1.3%, from $8.40 per
Mcfe for the three months ended March 31, 2006 to $8.51 per
Mcfe for the three months ended March 31, 2007, which
partially offset the production decline. Gas sales represented
87.9% of the total oil and
53
gas sales for the three months ended March 31, 2007
compared to 90.1% for the three months ended March 31, 2006.
Commodity derivative activities.
Realized gains from
our commodity derivative activity increased our revenues
$2.2 million for the three months ended March 31,
2007. In comparison, our commodity derivative activity increased
our revenues $1.4 million for the three months ended
March 31, 2006. The increase resulted from the relative
movement of the NYMEX gas prices in relation to the fixed
notional pricing for the respective time periods.
Overhead and services income.
Overhead and services
income for the three months ended March 31, 2007 increased
$11,000, or 9.5%, to $133,000 from $122,000 for the three months
ended March 31, 2006. This increase resulted from our
continued development of the Ozona Northeast field.
Lease operating expense.
Our lease operating
expenses increased $7,000, or 0.7%, for the three months ended
March 31, 2007 to $980,000 ($0.72 per Mcfe) from $973,000
($0.53 per Mcfe) for the three months ended March 31, 2006.
The primary factor in the slight increase in lease operating
expense was an increase of approximately $100,000 in our
estimated ad valorem taxes in the 2007 period, which partially
was offset by the release later in 2006 of one of our seven
rented compressors and an amine unit.
Severance and production taxes.
Our production taxes
decreased $5,000, or 1.3%, for the three months ended
March 31, 2007 to $375,000 from $380,000 for the three
months ended March 31, 2006. The decrease in production
taxes was a function of the reduced oil and gas sales in 2007,
offset partly by the timing of severance tax refunds in the 2006
period.
Depreciation, depletion and amortization
(DD&A).
Our DD&A expense decreased $200,000,
or 5.9%, to $3.1 million for the three months ended
March 31, 2007 from $3.3 million for the three months
ended March 31, 2006. Our DD&A expense per Mcfe
produced increased by $0.47, or 26.3%, to $2.26 per Mcfe for the
three months ended March 31, 2007, as compared to $1.79 per
Mcfe for the three months ended March 31, 2006. This
increase was primarily attributable to our drilling of mostly
proved undeveloped locations in the 2007 period, which were
previously recorded in our prior years reserves, which had
the effect of increasing production but did not increase
reserves to the same degree.
Exploration.
Our dry hole costs associated with
exploratory drilling increased $427,000 to $623,000 for the
three months ended March 31, 2007 from $196,000 for the
three months ended March 31, 2006. The 2007 dry hole costs
resulted from a mechanical failure in the drilling of a test
well in our Boomerang prospect.
General and administrative.
Our general and
administrative expenses increased $895,000, or 119.3%, to
$1.6 million for the three months ended March 31, 2007
from $750,000 for the three months ended March 31, 2006.
The increase in general and administrative expense was
principally due to bonus payments made in the first quarter of
2007 to cover tax liabilities incurred by management in
connection with the repayment of management notes in January
2007. See Certain relationships and related party
transactionsOther related party transactions.
Interest income (expense), net.
Our interest expense
increased $231,000, or 31.8%, to $956,000 for the three months
ended March 31, 2007 from $725,000 for the three months
ended March 31, 2006. This increase was a function of
increased borrowings in 2006 to fund our development of the
Ozona Northeast field and higher interest rates.
54
Income taxes.
Our provision (benefit) for income
taxes decreased $5.3 million, or 100.7%, to a benefit of
$35,000 for the three months ended March 31, 2007, from a
provision of $5.3 million for the three months ended
March 31, 2006. The decrease in income tax expense is
consistent with the decrease in our income before income taxes.
Our effective income tax rate for the three months ended
March 31, 2006 amounted to 33.7% compared with 5.7% for the
three months ended March 31, 2007. The decrease in the
effective rate results primarily from changes in the valuation
allowance provided against net operating loss carryovers for
Approach Oil & Gas Inc. We do not recognize a tax
benefit for the net operating loss carryovers of Approach
Oil & Gas Inc. based on our assessment of the
likelihood of Approach Oil & Gas Inc. being able to
utilize those carryovers to reduce future taxable income.
Subsequent to the combination of Approach Oil & Gas
Inc. and Approach Resources Inc., we believe that the net
operating loss carryovers of Approach Oil & Gas Inc.
will be available to offset our future taxable income, subject
to certain limits.
Years ended
December 31, 2005 and 2006
|
|
|
|
|
|
|
|
|
|
Year ended
December 31,
|
|
|
2005
|
|
2006
|
|
|
Net production (MMcfe)
|
|
|
5,012
|
|
|
6,744
|
Average sales prices (per Mcfe)
(before hedging)
|
|
$
|
8.63
|
|
$
|
6.92
|
Costs and expenses (in thousands):
|
|
|
|
|
|
|
Lease operating expenses
|
|
$
|
2,910
|
|
$
|
3,889
|
Production taxes
|
|
|
1,975
|
|
|
1,736
|
Depreciation, depletion and
amortization
|
|
|
8,006
|
|
|
14,541
|
General and administrative
|
|
|
3,067
|
|
|
2,930
|
|
|
Oil and gas sales.
Oil and gas sales increased
$12.6 million, or 31.1%, for the year ended
December 31, 2006 to $52.9 million from
$40.3 million for the year ended December 31, 2005.
The increase in sales principally resulted from a 34.6% increase
in production, as we drilled and completed 81 gross (53.5
net) wells in 2006. Additionally, the average price for gas
before the effect of hedging decreased $1.71 per Mcfe, or 19.8%,
from $8.63 per Mcfe in 2005 to $6.92 per Mcfe in 2006 as the
2005 period included the effects of the spike in gas prices
after Hurricane Katrina and Hurricane Rita. Gas sales
represented 89.7% of the total oil and gas sales in 2006
compared to 92.7% in 2005.
Commodity derivative activities.
Realized gains from
our commodity derivative activity increased our revenues
$6.2 million for the year ended December 31, 2006. In
comparison, realized losses from our commodity derivative
activity decreased our revenues $2.9 million for the year
ended December 31, 2005. During the years ended
December 31, 2005 and 2006, we used gas swaps to mitigate
commodity price risk. During 2005, commodity prices tended to be
higher than the notional prices specified in our swap
agreements, which resulted in a loss to us. In contrast, during
2006, commodity prices tended to be lower than the prices
specified in our swap agreements, which resulted in a gain to us.
55
Overhead and services income.
Overhead and services
income increased $106,000, or 26.0%, for the year ended
December 31, 2006 to $514,000 from $408,000 for the year
ended December 31, 2005. This increase resulted from the
addition of wells from our drilling program.
Lease operating expense.
Our lease operating
expenses increased $1.0 million, or 33.7%, for the year
ended December 31, 2006 to $3.9 million from
$2.9 million for the year ended December 31, 2005.
This increase primarily was the result of a $765,000 increase in
ad valorem taxes and from increased pumper costs of $200,000
from the continued development of the Ozona Northeast properties.
Severance and production taxes.
Our production taxes
decreased $239,000, or 12.1%, for the year ended
December 31, 2006 to $1.7 million from
$2.0 million for the year ended December 31, 2005. The
decrease in production taxes is a function of increased oil and
gas revenues that were more than offset by refunds received
applicable to prior years.
Depreciation, depletion and amortization
(DD&A).
Our DD&A expense increased
$6.5 million, or 81.6%, to $14.5 million for the year
ended December 31, 2006 from $8.0 million for the year
ended December 31, 2005. Our DD&A expense per Mcfe
produced increased by $0.56, or 35.0%, to $2.16 per Mcfe for the
year ended December 31, 2006, as compared to $1.60 per Mcfe
for the year ended December 31, 2005. This increase was
primarily attributable to increased production and increased oil
and gas property costs in 2006.
Exploration.
Our dry hole costs associated with
exploratory drilling increased $907,000 to $1.6 million for
the year ended December 31, 2006 from $700,000 for the year
ended December 31, 2005. We had nominal charges for
geological evaluation costs.
General and administrative.
Our general and
administrative expenses decreased $137,000, or 4.5%, to
$2.9 million for the year ended December 31, 2006 from
$3.1 million for the year ended December 31, 2005. The
decrease in general and administrative expense was principally
due to the accrual in 2005 of bonuses totaling approximately
$800,000 that did not recur in 2006, offset by increases in 2006
for professional fees, the number of employees and increases in
their compensation and benefits.
Interest income (expense), net.
Our interest expense
increased $3.0 million, or 375%, to $3.8 million for
the year ended December 31, 2006 from $802,000 for the year
ended December 31, 2005. This significant increase was a
function of increased borrowings under our revolving credit
facility and an increase in interest rates during 2006.
Income taxes.
Income taxes increased
$4.8 million, or 67.3%, to $11.8 million for the year
ended December 31, 2006 from $7.0 million for the year
ended December 31, 2005. Income taxes increased consistent
with our income before tax, offset by a decrease in our
effective tax rates, which amounted to 36.8% and 35.7% for the
years ended December 31, 2005 and 2006, respectively. Our
effective tax rate decreased due primarily to a change in the
tax law in the State of Texas which changed the tax from 4.5% of
net income to 1% of our margin, as defined in the
new law. Based on this change in the Texas tax law, we reduced
our deferred tax liability by approximately $1.1 million
for the year ended December 31, 2006.
56
Years ended
December 31, 2004 and 2005
|
|
|
|
|
|
|
|
|
|
Year ended
December 31,
|
|
|
2004
|
|
2005
|
|
|
Net production (MMcfe)
|
|
|
908
|
|
|
5,012
|
Average sales prices (per Mcfe)
(before hedging)
|
|
$
|
6.26
|
|
$
|
8.63
|
Costs and expenses (in thousands):
|
|
|
|
|
|
|
Lease operating expenses
|
|
$
|
179
|
|
$
|
2,910
|
Production taxes
|
|
|
406
|
|
|
1,975
|
Depreciation, depletion and
amortization
|
|
|
1,223
|
|
|
8,006
|
General and administrative
|
|
|
2,074
|
|
|
3,067
|
|
|
Oil and gas sales.
Oil and gas sales increased
$34.6 million to $40.3 million for the year ended
December 31, 2005 from $5.7 million for the year ended
December 31, 2004. This increase in oil and gas sales
principally resulted from the substantial increase in gas prices
in the aftermath of Hurricane Katrina and Hurricane Rita in the
third quarter of 2005 and our increased drilling activities in
2005. We drilled 113 and completed 110 successful wells during
the year ended December 31, 2005 in the Ozona Northeast
field in West Texas. In addition, our first few wells in the
Ozona Northeast field were not completed and producing until May
2004 and, therefore, the full year of production from these
wells in 2005 further contributed to the increase in gas and oil
production from 2004 to 2005.
Commodity derivative activities.
We had no commodity
derivatives in place prior to 2005. Realized losses from our
commodity derivative activity decreased our revenues
$2.9 million for the year ended December 31, 2005.
During the year ended December 31, 2005, we used gas swaps
to mitigate commodity price risk. During 2005, commodity prices
tended to be higher than the notional prices specified in our
swap agreements, which resulted in a loss to us.
Overhead and services income.
Overhead and services
income increased $278,000 to $408,000 for the year ended
December 31, 2005 from $130,000 for the year ended
December 31, 2004. This increase was a result of the
addition of wells from our drilling program.
Lease operating expense.
Lease operating expense
increased $2.7 million to $2.9 million for the year
ended December 31, 2005 from $179,000 for the year ended
December 31, 2004. This increase was primarily attributable
to our increased compression facility costs to handle the
increase in gas produced.
Severance and production taxes.
Our production taxes
increased $1.6 million to $2.0 million for the year
ended December 31, 2005 from $406,000 for the year ended
December 31, 2004. This increase was a function of
increased production and increased pricing.
Depreciation, depletion and amortization
(DD&A).
Our DD&A expense increased
$6.8 million to $8.0 million for the year ended
December 31, 2005 from $1.2 million for the year ended
December 31, 2004. Our DD&A expense per Mcfe produced
increased by $0.25, or 18.5%, to $1.60 per Mcfe for the year
ended December 31, 2005, as compared to $1.35 per Mcfe for
the year ended December 31, 2004. This increase was
primarily attributable to increased production and oil and gas
property costs in 2005.
57
General and administrative.
Our general and
administrative expenses increased $1.0 million, or 47.9%,
to $3.1 million for the year ended December 31, 2005
from $2.1 million for the year ended December 31,
2004. This increase was largely due to the accrual of $800,000
for bonuses in 2005.
Interest expense.
Our interest expense, net of
interest income, increased $1.0 million to $802,000 for the
year ended December 31, 2005 from interest income of
$201,000 for the year ended December 31, 2004. This
increase was primarily attributable to the increase in the
average amount borrowed under our revolving credit facility as a
result of increased costs from our drilling program.
Income taxes.
Our income tax expense increased for
the year ended December 31, 2005 compared to 2004 as net
income increased from 2004 to 2005. We recorded an accrual of
$580,000 as an estimate of the current taxes due for 2005.
Additionally, we recorded a deferred tax provision of
$6.4 million in 2005 largely due to the difference in
depletion, depreciation and capitalization methods for oil and
gas properties. No taxes were accrued for 2004 as we utilized
net operating loss carryforwards to offset any potential
liability.
Liquidity and
capital resources
For the three months ended March 31, 2007, the majority of
our cash was generated from operating and financing activities.
We used $4.5 million of proceeds from borrowings and cash
flow from operations of $5.7 million to fund
$9.7 million of capital expenditures related to our
drilling program activities. During the same three months in
2006, we used $12.6 million of cash flow from operations
and $11.2 million of proceeds from borrowings under our
revolving credit facility and available cash to fund
$24.6 million for our drilling program and
$1.3 million to repurchase shares and options.
Our primary sources of cash in 2006 were from financing and
operating activities. Approximately $18.2 million from
borrowings under our revolving credit facility,
$6.5 million from the issuance of common stock,
$3.5 million from a loan from one of our stockholders and
cash from operations were used to fund our drilling program and
the acquisition of another working interest in the Ozona
Northeast field.
For the year ended December 31, 2005, cash flow from
operations of $40.3 million, borrowings under our revolving
credit facility of $29.3 million and $3.0 million from
the issuance of common stock provided the funds to drill
additional wells in the Ozona Northeast field.
For the year ended December 31, 2004, operating cash flow
of $4.5 million combined with $22.4 million from the
issuance of common stock funded our initial drilling activities
in the Ozona Northeast field.
Our cash flow from operations is driven by commodity prices and
production volumes. Prices for oil and gas are driven by
seasonal influences of weather, national and international
economic and political environments and, increasingly, from
heightened demand for hydrocarbons from emerging nations,
particularly China and India. Our working capital is
significantly influenced by changes in commodity prices and
significant declines in prices could decrease our exploration
and development expenditures. Cash flows from operations were
primarily used to fund exploration and development of our
mineral interests. Our cash flows from operations increased
dramatically between 2004 and 2005 as we developed the Ozona
Northeast field. In comparing
58
2005 and 2006, our cash flows from operations declined slightly
due to a $6.2 million decrease in working capital
components partially offset by the increase in oil and gas sales
in 2006.
The following table summarizes our sources and uses of funds for
the periods noted:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three months
ended
|
|
|
|
Year ended
December 31,
|
|
|
March 31,
|
|
(in
thousands)
|
|
2004
|
|
|
2005
|
|
|
2006
|
|
|
2006
|
|
|
2007
|
|
|
|
|
Cash flows provided by operating
activities
|
|
$
|
4,527
|
|
|
$
|
40,304
|
|
|
$
|
34,110
|
|
|
$
|
12,616
|
|
|
$
|
5,687
|
|
Cash flows used in investing
activities
|
|
|
(26,859
|
)
|
|
|
(71,939
|
)
|
|
|
(59,189
|
)
|
|
|
(24,578
|
)
|
|
|
(9,717
|
)
|
Cash flows provided by financing
activities
|
|
|
22,474
|
|
|
|
32,199
|
|
|
|
26,771
|
|
|
|
9,918
|
|
|
|
4,493
|
|
|
|
|
|
|
|
Net increase (decrease) in cash
and cash equivalents
|
|
$
|
142
|
|
|
$
|
564
|
|
|
$
|
1,692
|
|
|
$
|
(2,044
|
)
|
|
$
|
463
|
|
|
|
Operating
activities
For the three months ended March 31, 2007, our cash flow
from operations was used for drilling activities. The
$5.7 million in cash flow generated in the first three
months of 2007 decreased $6.9 million from the first three
months of 2006 due mostly to lower oil and gas sales and higher
general and administrative expenses in the 2007 period.
Net cash provided by operating activities increased from
$4.5 million in 2004 to $40.3 million in 2005 and to
$34.1 million in 2006. The increase in 2005 resulted from
increased sales volumes from our successful drilling activities
and increased commodity prices. In comparing 2005 and 2006, our
cash flows from operations declined in part due to a
$6.2 million decrease in working capital components
partially offset by the increase in oil and gas sales and net
income in 2006 from our continued development of the Ozona
Northeast field in West Texas.
Investing
activities
Of the cash flows used in investing activities in the first
three months of 2007, $4.8 million was for the continued
development of the Ozona Northeast field, $1.8 million for
the drilling of the test wells in our Boomerang prospect,
$2.7 million for the acquisition of the El Vado East
leasehold and $400,000 for wells in our Cinco Terry project. For
the comparable period of 2006, $24.6 million was for the
drilling of Ozona Northeast wells.
The majority of our cash flows used in investing activities for
2004 through 2006 have been used for the continued development
of the Ozona Northeast field. In 2006, an additional
$4.1 million was used for undeveloped leaseholds in our
Cinco Terry and Boomerang fields, and $3.4 million was
invested in the initial wells in our Cinco Terry project.
We have established an exploratory and development budget of
$47.9 million and $66.0 million for 2007 and 2008,
respectively, after the completion of the acquisition of the Neo
Canyon interest. Our budgets are established based on expected
volumes to be produced and commodity prices.
59
Financing
activities
We borrowed $4.6 million under our revolving credit
facility in the first three months of 2007 as compared to
$11.2 million in the first three months of 2006. In
addition, $1.3 million was spent in the first three months
of 2006 to purchase common stock and related options from a
former employee.
During 2006, we sold approximately $6.5 million of common
stock. These proceeds were primarily used to fund the
acquisition of our Boomerang prospect and drilling costs for our
Cinco Terry project.
In February 2007, we entered into an amended and restated
$100 million revolving credit facility with The Frost
National Bank. As of December 31, 2006, we had an
outstanding balance under the previous facility of approximately
$47.6 million, with a borrowing base of $75 million.
The borrowing base is subject to adjustment twice each year. The
assessment by the bank petroleum engineers is based on their
evaluation of the future cash flows from proved oil and gas
reserves using the banks pricing parameters.
Our goal is to actively manage our borrowings to help us
maintain the flexibility to expand and invest, and to avoid the
problems associated with highly leveraged companies of large
interest costs and possible debt reductions restricting ongoing
operations.
We believe that cash flow from operations will finance
substantially all of our anticipated drilling, exploration and
capital needs and therefore, allow us to use our revolving
credit facility for possible acquisitions, temporary working
capital needs through 2008 and any expansion of our drilling
program.
60
Future capital
expenditures for 2007 and 2008
The following table summarizes information regarding our
historical 2006 and estimated 2007 and 2008 capital
expenditures. The 2007 and 2008 estimates include the interest
of Neo Canyon after completion of the acquisition of the 30%
working interest in the Ozona Northeast field that we do not
already own. We will be required to meet our needs from our
internally generated cash flow, debt financings and equity
financings. The estimated capital expenditures are subject to
change depending upon a number of factors, including the results
of our development and exploration efforts, the availability of
sufficient capital resources to us and other participants for
drilling prospects, economic and industry conditions at the time
of drilling, including prevailing and anticipated prices for oil
and gas and the availability of drilling rigs and crews, our
financial results and the availability of leases on reasonable
terms and our ability to obtain permits for the drilling
locations.
|
|
|
|
|
|
|
|
|
|
|
|
|
Historical
|
|
Estimated
|
|
|
year ended
|
|
Year ending
|
|
|
December 31,
|
|
December 31,
|
(in
thousands)
|
|
2006
|
|
2007
|
|
2008
|
|
|
Capital expenditures:
|
|
|
|
|
|
|
|
|
|
Ozona Northeast
|
|
$
|
52,108
|
|
$
|
34,300
|
|
$
|
50,500
|
Cinco Terry
|
|
|
3,176
|
|
|
2,200
|
|
|
4,100
|
Western Kentucky
|
|
|
3,873
|
|
|
4,600
|
|
|
6,600
|
Northern New Mexico
|
|
|
|
|
|
3,800
|
|
|
4,500
|
Geological, geophysical and other
|
|
|
|
|
|
4,400
|
|
|
800
|
|
|
|
|
|
|
Total capital expenditures
|
|
$
|
59,157
|
|
$
|
49,300
|
|
$
|
66,500
|
|
|
Credit
facility
In February 2007, we entered into an amended and restated
$100 million revolving credit facility with The Frost
National Bank. In June 2007, we extended the due date of any
balance outstanding at maturity to July 2010. The availability
of funds under our revolving credit facility is subject to a
borrowing base which was initially set at, and currently is,
$75 million. The borrowing base will be redetermined every
six months or, upon the election by us or the bank, one
additional time each calendar year.
Our revolving credit facility provides for interest on
outstanding amounts to accrue at a rate calculated, at our
option, at either (i) the adjusted base rate, or
(ii) the London Interbank Offered Rate plus a margin which
ranges from 1.25% to 2.0% per annum, as applicable, as amounts
outstanding under our revolving credit facility increase as a
percentage of the borrowing base. In addition, we pay an annual
commitment fee of 0.375% of non-utilized borrowings available
under our revolving credit facility.
We are subject to a financial covenant requiring maintenance of
a minimum modified ratio of current assets to current
liabilities. In addition, we are subject to covenants
restricting cash dividends and other restricted payments,
transactions with affiliates, incurrence of other debt,
consolidations and mergers, the level of operating leases,
assets sales, investments in other entities and liens on
properties.
61
Loans under our revolving credit facility are secured by first
priority liens on substantially all of our West Texas assets
including equity interests in our subsidiaries. All outstanding
amounts under our revolving credit facility are due and payable
in July 2010.
We anticipate that the proceeds to us from this offering will be
used to pay off outstanding borrowings under our revolving
credit facility. As of December 31, 2006 and March 31,
2007, the outstanding balance under our revolving credit
facility was $47.6 million and $52.2 million,
respectively.
Contractual
commitments
We have a lease for our current office space in Fort Worth,
Texas, that expires in May 2009. Our obligation under this lease
is approximately $119,000 per year. In April 2007, we signed a
five-year lease for approximately 13,000 square feet of
space in Fort Worth, Texas. In November 2007, we will begin
rent payments of approximately $20,000 per month, including
common area expenses. We expect to sublet our current office
space.
The following table summarizes these commitments as of
May 31, 2007 (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Less than
|
|
|
|
|
|
More than
|
Contractual
obligations
|
|
Total
|
|
1 year
|
|
1-3 years
|
|
3-5 years
|
|
5 years
|
|
|
Long-term debt
obligationsrevolving credit facility
|
|
$
|
52,169
|
|
$
|
|
|
$
|
|
|
$
|
52,169
|
|
$
|
|
Operating lease obligations(1)
|
|
|
1,592
|
|
|
321
|
|
|
625
|
|
|
532
|
|
|
114
|
Asset retirement obligations
|
|
|
155
|
|
|
|
|
|
|
|
|
|
|
|
155
|
Employment agreements with
executive officers and other key personnel(2)
|
|
|
1,946
|
|
|
775
|
|
|
1,171
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
55,862
|
|
$
|
1,096
|
|
$
|
1,796
|
|
$
|
52,701
|
|
$
|
269
|
|
|
|
|
|
(1)
|
|
Operating lease obligation is for
office space.
|
|
(2)
|
|
These agreements are automatically
renewed for successive terms of one year unless employment is
terminated at the end of the term by written notice given to the
employee not less than 60 days prior to the end of such
term. Our maximum commitment under the employment agreements,
which would apply if the employees covered by these agreements
were all terminated without cause, is approximately $1,171,000
at December 31, 2007. See Executive
compensationOther benefitsEmployment agreements and
other arrangements.
|
Off-balance sheet
arrangements
From time to time, we enter into off-balance sheet arrangements
and transactions that can give rise to off-balance sheet
obligations. As of December 31, 2006, the off-balance sheet
arrangements and transactions that we have entered into include
undrawn letters of credit, operating lease agreements and gas
transportation commitments. We do not believe that these
arrangements are reasonably likely to materially affect our
liquidity or availability of, or requirements for, capital
resources.
Quantitative and
qualitative disclosure about market risk
Some of the information below contains forward-looking
statements. The primary objective of the following information
is to provide forward-looking quantitative and qualitative
information about our potential exposure to market risks. The
term market risk refers to the risk of
62
loss arising from adverse changes in oil and gas prices, and
other related factors. The disclosure is not meant to be a
precise indicator of expected future losses, but rather an
indicator of reasonably possible losses. This forward-looking
information provides an indicator of how we view and manage our
ongoing market risk exposures. Our market risk sensitive
instruments were entered into for hedging and investment
purposes, not for trading purposes.
Commodity price
risk
We enter into financial swaps and collars to hedge future oil
and gas production to mitigate portions of the risk of market
price fluctuations.
To designate a derivative as a cash flow hedge, we document at
the hedges inception our assessment as to whether the
derivative will be highly effective in offsetting expected
changes in cash flows from the item hedged. This assessment,
which is updated at least quarterly, is generally based on the
most recent relevant historical correlation between the
derivative and the item hedged. The ineffective portion of the
hedge, if any, is calculated as the difference between the
change in fair value of the derivative and the estimated change
in cash flows from the item hedged.
If, during a hedges term, we determine the hedge is no
longer highly effective, hedge accounting is prospectively
discontinued and any remaining unrealized gains or losses on the
effective portion of the derivative are reclassified to earnings
when the underlying transaction occurs. If it is determined that
the designated hedge transaction is not likely to occur, any
unrealized gains or losses are recognized immediately in the
consolidated statements of income as a derivative fair value
gain or loss.
As of March 31, 2007, we had two gas swaps in place for the
remainder of 2007 for an average volume of 243,000 MMBtu
per month. One of the swaps provides for us to be paid a
notional price averaging $8.48 as compared to the floating NYMEX
price for that period. In addition, we have in place a WAHA
basis swap of $1.02 per MMBtu for the remainder of 2007. At
December 31, 2006 and March 31, 2007, the fair value
of our open derivative contracts was an asset of approximately
$4.5 million and a liability of $121,312, respectively.
In May 2007, we entered into a gas collar for 2008 based on the
NYMEX floating MMBtu price with a $7.50 floor and a $11.45
ceiling. In addition, we entered into a WAHA basis swap for 2008
for $0.69 per MMBtu. Both of these hedges were for an average
volume of approximately 186,000 MMBtu per month.
We have reviewed the financial strength of our hedge
counterparty and believe our credit risk to be minimal. Our
hedge counterparty is a participant in our credit facility and
the collateral for the outstanding borrowings under our
revolving credit facility is used as collateral for our hedges.
63
Business
Overview
We are an independent energy company engaged in the exploration,
development, exploitation, production and acquisition of
unconventional natural gas and oil properties. Our principal
operations are located in the Ozona Northeast field in West
Texas, where we originally acquired approximately 28,000 gross
(27,000 net) acres of leasehold interests in 2004. Since that
time, through a series of strategic leasehold acquisitions, we
have increased our West Texas acreage to 67,000 gross (52,000
net) acres located in the Ozona Northeast field and our nearby
Cinco Terry project. Our management team has extensive
experience finding and exploiting unconventional reservoirs,
particularly tight gas sands like Ozona Northeast, by applying
advanced completion, fracturing and drilling techniques.
Substantially all of our growth has been through our own
drilling efforts. Since 2004, we have added approximately 149
Bcfe of proved gas and oil reserves from unconventional
reservoir formations.
At December 31, 2006, all of our proved reserves and
production were located in our West Texas operating area and
substantially all of those reserves and production were located
in the Ozona Northeast field. As of such date, we owned working
interests in 241 gross (226 net) producing wells with an average
net production of approximately 22 MMcfe/d for the month of
December 2006. At December 31, 2006, our estimated
total proved gas and oil reserves were approximately 149 Bcfe
with a reserve life index of approximately 19 years. Our proved
reserves are 94% gas and 51% proved developed. As the operator
of substantially all of our proved reserves, we have a high
degree of control over capital expenditures and other operating
matters.
As of December 31, 2006, we had identified a total of 795
drilling locations, of which 668 were located in the Ozona
Northeast field and 127 in our Cinco Terry project. Of the
total, 203 locations were classified as proved. The final
determination of whether or not to drill any particular well,
including those wells currently budgeted, will depend on a
number of factors, including the results of our development and
exploration efforts, the availability of sufficient capital
resources to us and other participants for drilling prospects,
economic and industry conditions at the time of drilling,
including prevailing and anticipated prices for gas and oil and
the availability of drilling rigs and crews, our financial
results, the availability of leases on reasonable terms and our
success in obtaining permits for potential drilling locations.
Our growth efforts are focused primarily on finding and
developing natural gas reserves in known tight gas sands and
shale areas onshore in the United States. Since May 2006,
we have acquired leasehold interests covering 74,000 gross
(44,000 net) acres in Western Kentucky and 90,000 gross (81,000
net) acres in Northern New Mexico. In total we have assembled
leasehold interests of 231,000 gross (177,000 net) acres in our
three operating areas West Texas (Wolfcamp, Canyon
Sands and Ellenburger), Western Kentucky (New Albany Shale) and
Northern New Mexico (Mancos Shale).
Strategy
Our strategy is to increase stockholder value by profitably
growing our reserves, production, cash flow and earnings using a
balanced program of (1) developing existing properties,
64
(2) exploring and exploiting undeveloped properties,
(3) completing strategic acquisitions and
(4) maintaining financial flexibility. The following are
key elements of our strategy:
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Continue to develop our existing West Texas properties
.
We intend to develop further the significant remaining potential
of our West Texas properties, where we have identified
795 drilling locations.
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|
We acquired our initial position in the Ozona Northeast field
through a Farmout Agreement in January 2004. The agreement
covered 28,000 gross (27,000 net) acres. During 2005, we
leased an additional 17,000 gross (17,000 net) acres. We
began our drilling program late in the first quarter of 2004 and
by year-end we had drilled 54 wells with an 85% success
rate. In early 2005, in response to increased gas prices, we
increased our drilling rig inventory from two rigs to four rigs
and filed for optional
20-acre
down
spacing with the Texas Railroad Commission. By the end of 2005,
we had drilled another 120 wells with a 96% success rate.
During the first quarter of 2006, the Texas Railroad Commission
granted the
20-acre
down
spacing, which substantially increased our proved undeveloped
inventory. During the first half of 2006, we elected not to
renew two of our four drilling rig contracts due to increased
rig pricing. By year-end 2006, we had drilled 79 additional
wells with a 97% success rate. We currently plan to continue to
develop the Ozona Northeast field by drilling an additional
43 wells in 2007 and 64 wells in 2008. We estimate
that as of December 31, 2006, we had 668 identified
drilling locations in the Ozona Northeast field, 192 of which
were proved.
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In January 2007 we implemented several changes to our drilling
and completion techniques for our developmental Canyon wells in
Ozona Northeast, where we have 688 remaining drilling
locations. Primarily, we streamlined our casing design and
modified our stimulation process. We estimate that these changes
have resulted in current drilling and completion cost savings of
approximately $50,000 per well, based on current markets for
drilling services and equipment.
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We believe our Cinco Terry project has significant potential
reserves in both the (i) established Canyon and Ellenburger
formations and (ii) shallower and less-explored Wolfcamp
trend. During the second quarter of 2007, we recompleted one of
our existing wells into the Wolfcamp formation and we plan to
drill two Canyon/Ellenburger wells in the third quarter of 2007
and two Canyon/Ellenburger wells in the fourth quarter of 2007.
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Pursue unconventional gas and oil
opportunities.
With our Boomerang and El Vado East
prospects, we have 164,000 gross acres of unexplored shale
gas and oil inventory to explore and produce. We plan to extend
our three Western Kentucky vertical test wells horizontally into
the New Albany Shale in the third quarter of 2007 and drill four
additional evaluation wells in the fourth quarter of 2007. We
also plan to identify and drill up to four Mancos Shale wells in
El Vado East by the end of this year. We intend to support our
unconventional shale gas and oil exploration with cash flow from
our long-lived tight gas properties in West Texas.
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Acquire strategic assets.
We continually review
opportunities to acquire producing properties, undeveloped
acreage and drilling prospects. We focus particularly on
opportunities where we believe our reservoir management and
operational expertise in unconventional gas and oil properties
will enhance value and performance. We remain focused on
unconventional resource opportunities, but also look at
conventional opportunities based on individual project
economics. We may enter into hedging agreements in connection
with future
|
65
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|
|
acquisitions to protect our return on investment. Our management
team members have gained significant acquisition experience
during their careers with Approach and previous employers.
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Operate our producing properties as a low-cost
producer.
We strive to minimize our operating costs by
concentrating our assets within geographic areas where we can
consolidate operating control and thus capture operating
efficiencies. We are the operator of substantially all of our
producing properties and plan to continue to operate
substantially all of our producing properties in the future.
Operating control allows us to better manage timing and risk as
well as the cost of exploration and development, drilling and
ongoing operations. We believe that in the competitive market
for drilling rigs it is advantageous to have the flexibility to
control the length of rig commitments in order to secure service
at the lowest cost.
|
Competitive
strengths
We believe our historical success is, and future performance
will be, directly related to the following combination of
strengths which enable us to implement our strategy:
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Experienced executive and technical team with significant
employee ownership
. The members of our executive and
technical team (including our Chief Executive Officer) have an
average of over 26 years of experience in the oil and gas
industry and significant experience in building and managing
independent oil and gas companies. The majority of our executive
and technical team have spent their entire careers developing
unconventional gas and oil properties. Our technical team
includes two geologists and three petroleum engineers with
industry expertise in working with shallow to intermediate depth
tight gas sand wells. Our team has a proven record of analyzing
complex structural and stratigraphic formations using
3-D
seismic
and geological expertise, producing and optimizing gas
reservoirs and drilling and completing unconventional gas
reservoirs. Further, our professionals have developed completion
techniques that enhance initial production rates and ultimate
reserve recoveries in mature tight gas fields. Our team was
responsible for the introduction of
CO
2
foam fracs to West Texas Canyon Sands tight gas fields and
certain areas of the Piceance Basin in Colorado in the late
1980s. This same team has presented technical papers and
delivered numerous industry presentations covering
CO
2
foam fracing on low pressure, water-sensitive tight gas
reservoirs. Several of our directors also have significant
experience in managing both public and private oil and gas
companies. Our management team and employees will own
approximately % of our common stock after this
offering, aligning their objectives with those of our
stockholders.
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Low risk, multi-year drilling inventory.
We have
identified 795 drillable, low to moderate risk locations on our
West Texas properties, providing us with approximately
10 years of drilling inventory at our current drilling
rate. Our technical teams ability to locate and execute on
repeatable low-risk drilling opportunities in our large and
productive West Texas acreage holdings has helped us to achieve
a drilling success rate of 94% since our inception. In addition,
our technical expertise also has allowed us to improve our
production rates and ultimate hydrocarbon recoveries on our
wells.
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Stable producing asset base.
We own an operated
asset base comprising long-lived reserves. Approximately 94% of
our reserves are gas, and all of our proved reserves are located
in West Texas. These properties should produce stable cash flows
to fund our development, exploitation and exploration
opportunities.
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66
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Large acreage positions.
We are a significant
acreage holder in each of our three primary operating areas with
an aggregate leasehold position of 231,000 gross (177,000
net) acres. We believe we have assembled a portfolio of
properties, both in prolific producing natural gas and oil
fields and in under-explored reservoirs, that would be difficult
to replicate.
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Operated asset base.
We operate substantially all of
our estimated reserves. By maintaining operating control, we are
able to more effectively control our expenses, capital
allocation and the timing and method of exploitation and
development of our properties.
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Low cost structure.
Our reserve potential in our
operating areas, our technical expertise and high drilling
success have allowed us to achieve relatively low finding and
development costs. Since our inception and through
December 31, 2006, we have invested approximately
$200 million to drill and complete 241 wells in our
West Texas operating areas, achieving an average finding and
development cost of $1.38 per Mcfe. SeeHistorical
finding and development costs. During the same time
period, our lease operating costs, including production taxes,
averaged $0.91 per Mcfe.
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Financial flexibility.
Upon the completion of this
offering, we expect to have approximately
$ million in cash, no
long-term debt and at least
$ million available for
borrowings under our revolving credit facility, providing us
with significant financial flexibility to pursue our business
strategy.
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Control of gathering infrastructure and gas
marketing.
We own and operate approximately
72 miles of gas gathering lines in West Texas that collect
and transport our production to multiple delivery points for
several regional and interstate pipelines. Owning and operating
this infrastructure allows us to maintain greater control of our
gathering pressures and to minimize down time associated with
the system. We intend to purchase or construct additional gas
gathering assets as necessary to fully develop our tight gas and
shale opportunities in West Texas, Western Kentucky and Northern
New Mexico.
|
Areas of
operation
West
Texas
The Wolfcamp Canyon Sands play is the predominant producer in
Edwards, Sutton, Schleicher and Crockett Counties in West Texas.
There have been over 11,800 Canyon Sands wells drilled to date.
Major canyon fields located in this area are Sawyer Canyon,
Ozona Canyon, Ozona Northeast Proper Canyon, Davidson Ranch
Canyon, Henderson Canyon and Ozona Northeast Canyon. To date,
the combined production from these fields is over 3.8 Tcfe.
The Canyon Sands are a tight sand and siltstone reservoir that
requires large fracture stimulation. The large independent
companies currently active in the Canyon Sands play include
Anadarko Petroleum Corp., Dominion Resources Inc. and Encore
Acquisition Company along with several smaller companies,
including Approach.
Ozona
Northeast field (Canyon Sands)
The Ozona Northeast field, in Crockett and Schleicher counties,
Texas, is our largest operating area on the basis of proved
reserves and production. The Ozona Northeast field is one of the
top 100 gas fields in the United States in both
reserves and production. In 2004, we entered the field through a
farmout arrangement and have since increased our total acreage
position to 45,000 gross (44,000 net) acres. In February
2004, we drilled our first well, and, as of
67
December 31, 2006, we had 237 producing wells with proved
reserves of 147 Bcfe. During that period we have achieved
an average compound annual production growth rate of over 100%
as a result of our own drilling efforts. We have identified 668
additional drilling locations in the field, and we estimate that
completed costs per location currently are approximately
$770,000, based on current markets for drilling services and
equipment.
Cinco Terry
project (Wolfcamp, Canyon Sands and Ellenburger)
Since late 2005, we have leased and acquired options to lease
22,000 gross (8,000 net) acres five miles west of our Ozona
Northeast field in order to evaluate the Wolfcamp, Canyon and
Ellenburger formations. As of May 31, 2007, we had drilled
and completed three Canyon wells and one Ellenburger well at a
total cost of $5.9 million gross and $3.0 million net.
Proved reserves in the Cinco Terry project are estimated to be
1.8 Bcfe at December 31, 2006. Wolfcamp wells in this
area have demonstrated significant commercial production, and we
are evaluating the formation for possible horizontal
completions. Based upon data collected in the process of
drilling the Canyon and Ellenburger wells, we believe additional
success could be achieved in the shallower Wolfcamp formation.
Ozona pipeline
system
We own and operate 72 miles of gas gathering lines for the
Ozona Northeast and Cinco Terry production that transport our
gas to a custody transfer point. We rent all compression
equipment, which minimizes our overall cost to add or remove
compression depending on field requirements. Owning and
operating the gathering systems allows us to maintain control of
our gathering pressures as well as minimizing down time
associated with the system. Our system delivers into Ozona
Pipeline Energy Company and Duke Energy Corp.s pipeline
system.
Western
Kentucky
Boomerang
prospect (New Albany Shale)
Our Boomerang prospect is a 74,000 gross (44,000 net) acre
New Albany Shale play located in Western Kentucky in an
under-explored area of the Illinois Basin. The New Albany Shale
produces both biogenic and thermogenic gas from fractured
reservoirs across a wide area in Illinois and Indiana.
Thermogenic gas fields have been successfully developed in
Kentucky, most notably in the Appalachian Basin part of Eastern
Kentucky. Renewed interest in the Illinois Basin shale gas play
has resulted in recent activity by several independent operators.
We believe the attributes of the New Albany Shale in our
Boomerang prospect make it a promising resource play,
particularly with the introduction of horizontal drilling
technology. In the first quarter of 2007, we drilled the last of
three vertical test wells. We have contracted to have core
samples from these three wells analyzed for their geological,
petrophysical, geomechanical, geochemical and production
properties. We expect to begin the horizontal completion of
these three test wells in the third quarter of 2007. After
evaluating the results of our initial drilling and completion
activities, we will determine our development program in the
Boomerang prospect.
68
Northern New
Mexico
El Vado East
prospect (Mancos Shale)
Our El Vado East prospect is a 90,000 gross (81,000 net)
acre Mancos Shale play located in the Chama Basin in Northern
New Mexico in proximity to several highly productive fields,
including the West and East Puerto Chiquito fields and the
Boulder field. The West Puerto Chiquito Field has produced over
17 MMBbls, the East Puerto Chiquito Field has produced over
4 MMBbls and the Boulder Field has produced approximately
1.8 MMBbls. Other producing Mancos Shale fields in the
San Juan Basin include the Gavilan and Verde Fields. The
Mancos Shale is a thick, organic-rich Upper Cretaceous marine
shale. We believe considerable exploration and development
potential exists for this play.
Although our primary objective in the El Vado East prospect is
the Mancos Shale, the possibility of finding commercial
production in the Dakota, Morrison, Todilto and Entrada
formations is a secondary objective. We anticipate spudding our
initial test well in the El Vado East, which we expect to be the
first of four vertical test wells, in the third quarter of 2007.
Depending on the initial results of these wells, we may elect to
shoot
3-D
seismic over a portion of this prospect at locations which have
yet to be identified.
Estimated proved
reserves
As of December 31, 2006, all of our proved reserves and
production were located in our West Texas operating area and
substantially all of those reserves and production were located
in the Ozona Northeast field. The following table sets forth a
summary of our estimated proved reserves and estimated average
daily net production for the month ended December 31, 2006.
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|
|
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Production for
the month ended
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Estimated proved
reserves at December 31, 2006
|
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December 31,
2006
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|
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Percent
|
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|
Identified
|
|
Net
|
|
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Developed
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Undeveloped
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Total
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|
of total
|
|
PV-10(1)
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|
drilling
|
|
average
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Percent
|
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|
(Bcfe)
|
|
(Bcfe)
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|
(Bcfe)
|
|
reserves
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|
(millions)
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|
locations(2)
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|
MMcfe/d
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|
of
total
|
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|
Ozona Northeast
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|
74.9
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|
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72.1
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|
147.0
|
|
|
99%
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$
|
175.7
|
|
|
668
|
|
|
21.9
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|
99%
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Cinco Terry
|
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|
0.9
|
|
|
0.9
|
|
|
1.8
|
|
|
1%
|
|
|
4.2
|
|
|
127
|
|
|
0.3
|
|
|
1%
|
|
|
|
|
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Total
|
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|
75.8
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|
|
73.0
|
|
|
148.8
|
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|
100%
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|
$
|
179.9
|
|
|
795
|
|
|
22.2
|
|
|
100%
|
|
|
|
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(1)
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PV-10
is a non-GAAP financial measure and generally differs from
standardized measure of discounted future net cash flows, the
most directly comparable GAAP financial measure, because it does
not include the effects of income taxes on future net revenues.
See Selected historical combined financial
dataReconciliation of non-GAAP financial measures
for our definition of
PV-10
and a
reconciliation of
PV-10
to the
standardized measure of discounted future net cash flows. Our
calculation of
PV-10
set
forth in this table is based on gas and oil and condensate
prices actually received by us on December 31, 2006, held
flat for the life of the reserves. The weighted average price
over the life of the Ozona Northeast reserves was $6.55 per Mcf
of gas and $58.05 per Bbl of oil. The weighted average price
over the life of the Cinco Terry reserves was $5.65 per Mcf of
gas and $58.05 per Bbl of oil.
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(2)
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Represents total gross drilling
locations identified by management as of December 31, 2006.
Of the total, 203 locations are classified as proved. The final
determination with respect to the drilling of any well,
including those currently budgeted, will depend on a number of
factors, including the results of our development and
exploration efforts, the availability of sufficient capital
resources to us and other participants for drilling prospects,
economic and industry conditions at the time of drilling,
including prevailing and anticipated prices for gas and oil and
the availability of drilling rigs and crews, our financial
results and the availability of leases on reasonable terms and
permitting for the potential drilling locations.
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69
Operating
data
The following table presents certain information with respect to
our historical operating data for the years ended
December 31, 2004, 2005 and 2006 and for the three months
ended March 31, 2007 and combined pro forma operating data
for the year ended December 31, 2006 and the three months
ended March 31, 2007, after giving effect to our
acquisition of the Neo Canyon interest:
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|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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|
Pro
forma
|
|
|
|
|
|
|
|
|
Three
|
|
|
|
Three
|
|
|
|
|
|
|
|
|
months
|
|
Year
|
|
months
|
|
|
|
|
|
|
|
|
ended
|
|
ended
|
|
ended
|
|
|
Year ended December 31,
|
|
March 31,
|
|
December 31,
|
|
March 31,
|
|
|
2004
|
|
2005
|
|
2006
|
|
2007
|
|
2006
|
|
2007
|
|
|
Gross wells
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Drilled
|
|
|
54
|
|
|
120
|
|
|
83
|
|
|
9
|
|
|
83
|
|
|
9
|
Completed
|
|
|
46
|
|
|
115
|
|
|
81
|
|
|
8
|
|
|
81
|
|
|
8
|
Net wells
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Drilled
|
|
|
34.9
|
|
|
77.2
|
|
|
55.1
|
|
|
6.3
|
|
|
79.6
|
|
|
9.0
|
Completed
|
|
|
29.6
|
|
|
74.8
|
|
|
53.5
|
|
|
5.6
|
|
|
77.3
|
|
|
8.0
|
Net production data
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net volume (MMcfe)
|
|
|
908
|
|
|
5,012
|
|
|
6,744
|
|
|
1,357
|
|
|
9,580
|
|
|
1,910
|
Average daily volume (MMcfe/d)
|
|
|
4
|
|
|
14
|
|
|
18
|
|
|
15
|
|
|
26
|
|
|
21
|
Average sales price (per
Mcfe)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Average sales price (without hedge)
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|
$
|
6.26
|
|
$
|
8.63
|
|
$
|
6.92
|
|
$
|
6.92
|
|
$
|
6.91
|
|
$
|
6.91
|
Average sales price (with hedge)
|
|
|
6.26
|
|
|
8.05
|
|
|
7.84
|
|
|
8.51
|
|
|
7.56
|
|
|
8.04
|
Expenses (per Mcfe)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating
|
|
$
|
0.20
|
|
$
|
0.58
|
|
$
|
0.58
|
|
$
|
0.72
|
|
$
|
0.60
|
|
$
|
0.74
|
Production taxes
|
|
|
0.45
|
|
|
0.39
|
|
|
0.26
|
|
|
0.28
|
|
|
0.26
|
|
|
0.28
|
General and administrative
|
|
|
2.28
|
|
|
0.61
|
|
|
0.43
|
|
|
1.21
|
|
|
0.31
|
|
|
0.86
|
Depreciation, depletion and
amortization
|
|
|
1.35
|
|
|
1.60
|
|
|
2.16
|
|
|
2.26
|
|
|
2.30
|
|
|
2.47
|
|
|
70
The estimates in the table below of proved reserves as of
December 31, 2006 are based on a reserve report prepared by
us and audited by DeGolyer & MacNaughton.
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|
|
|
|
|
|
|
As of
|
|
Pro
forma
|
|
|
December 31,
|
|
December 31,
|
|
|
2006
|
|
2006(1)
|
|
|
Estimated proved reserves
|
|
|
|
|
|
|
Gas (Bcf)
|
|
|
98.7
|
|
|
139.8
|
Oil (MMBbls)
|
|
|
1.1
|
|
|
1.5
|
|
|
|
|
|
|
Total proved reserves (Bcfe)
|
|
|
105.4
|
|
|
148.8
|
Total proved developed reserves
(Bcfe)
|
|
|
53.1
|
|
|
75.8
|
PV-10
(millions)(2)
|
|
|
|
|
|
|
Proved developed reserves
|
|
$
|
112.8
|
|
$
|
158.3
|
Proved undeveloped reserves
|
|
|
15.6
|
|
|
21.6
|
|
|
|
|
|
|
Total
PV-10
value
|
|
$
|
128.4
|
|
$
|
179.9
|
|
|
|
|
|
(1)
|
|
Gives effect to our acquisition of
the Neo Canyon interest.
|
|
(2)
|
|
PV-10
is a non-GAAP financial measure and generally differs from
standardized measure of discounted future net cash flows, the
most directly comparable GAAP financial measure, because it does
not include the effects of income taxes on future net revenues.
See Selected historical combined financial
dataReconciliation of non-GAAP financial measures
for our definition of
PV-10
and a
reconciliation of
PV-10
to the
standardized measure of discounted future net cash flows. Our
calculation of
PV-10
set
forth in this table is based on gas and oil and condensate
prices actually received by us on December 31, 2006, held
flat for the life of the reserves. The weighted average price
over the life of the Ozona Northeast reserves was $6.55 per Mcf
of gas and $58.05 per Bbl of oil. The weighted average price
over the life of the Cinco Terry reserves was $5.65 per Mcf of
gas and $58.05 per Bbl of oil.
|
Development and
exploration projects
The following table summarizes our historical 2006 and our
estimated 2007 and 2008 capital expenditures. The estimated 2007
and 2008 capital expenditures shown are preliminary full year
estimates. The estimated capital expenditures are subject to
change depending upon a number of factors, including
availability of capital, drilling results, oil and gas prices,
costs of drilling and completion and availability of drilling
rigs, equipment and labor.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Historical(1)
|
|
|
|
|
|
|
|
|
Three months
|
|
Estimated(2)
|
|
|
Year ended
|
|
ended
|
|
Year ending
|
|
|
December 31,
|
|
March 31,
|
|
December 31,
|
(in
thousands)
|
|
2006
|
|
2007
|
|
2007
|
|
2008
|
|
|
Capital expenditures:
|
|
|
|
|
|
|
|
|
|
|
|
|
Ozona Northeast
|
|
$
|
52,108
|
|
$
|
4,793
|
|
$
|
34,300
|
|
$
|
50,500
|
Cinco Terry
|
|
|
3,176
|
|
|
374
|
|
|
2,200
|
|
|
4,100
|
Western Kentucky
|
|
|
3,873
|
|
|
1,858
|
|
|
4,600
|
|
|
6,600
|
Northern New Mexico
|
|
|
|
|
|
2,660
|
|
|
3,800
|
|
|
4,500
|
Geological, geophysical and other
|
|
|
|
|
|
31
|
|
|
4,400
|
|
|
800
|
|
|
|
|
|
|
Total capital expenditures
|
|
$
|
59,157
|
|
$
|
9,716
|
|
$
|
49,300
|
|
$
|
66,500
|
|
|
71
|
|
|
(1)
|
|
Historical amounts here include
actual amounts incurred to the interest of Approach Resources
Inc. and Approach Oil & Gas Inc.
|
|
(2)
|
|
Estimated capital expenditures for
2007 and 2008 include the acquisition of the Neo Canyon interest
in combination with the interest of Approach Resources Inc. and
Approach Oil & Gas Inc. as if the Neo Canyon interest
were acquired on January 1, 2007.
|
Historical
finding and development costs
From our inception in September 2002 to December 31, 2006,
our acquisition, finding and development costs have averaged
$1.38 per Mcfe. The cost of finding and developing reserves is
calculated by taking the sum of the cost incurred for
exploration, development and acquisition for the period, and
dividing such amount by the total proved reserve additions for
the period. The calculation does not include estimated future
development costs for proved undeveloped reserves, which at
December 31, 2006 totaled $108.5 million. Management
believes that this information is useful to an investor in
evaluating Approach because it measures the efficiency of a
company in adding proved reserves as compared to others in the
industry.
|
|
|
|
|
|
September 13,
2002 (inception) through
|
($ in thousands,
unless otherwise indicated)
|
|
December 31,
2006
|
|
|
All in average F&D
cost:
|
|
|
|
Proved properties acquisition costs
|
|
$
|
11,948
|
Unproved properties acquisition
costs
|
|
|
4,992
|
Exploration costs
|
|
|
6,285
|
Development costs
|
|
|
140,153
|
|
|
|
|
Total
|
|
$
|
163,378
|
|
|
|
|
Reserve purchases, extensions,
discoveries and revisions (Mmcfe)
|
|
|
118,053
|
|
|
|
|
F&D cost per Mcfe
|
|
$
|
1.38
|
|
|
Markets and
customers
The revenues generated by our operations are highly dependent
upon the prices of, and demand for, gas and oil. The price we
receive for our gas and oil production depends on numerous
factors beyond our control, including seasonality, the
conditions of the United States economy, particularly in the
manufacturing sector, political conditions in other oil and gas
producing countries, the extent of domestic production and
imports of gas and oil, the proximity and capacity of gas
pipelines and other transportation facilities, demand for oil
and gas, the marketing of competitive fuels and the effects of
state and federal regulation. The oil and gas industry also
competes with other industries in supplying the energy and fuel
requirements of industrial, commercial and individual consumers.
During the year ended December 31, 2006, Ozona Pipeline was
our most significant purchaser, accounting for approximately
89.6% of our total 2006 gas and oil sales excluding realized
hedge settlements.
72
Productive
wells
The following table sets forth the number of productive gas and
oil wells in which we owned a working interest at
December 31, 2006.
|
|
|
|
|
|
|
|
|
|
Gross
|
|
Net
|
|
|
Gas
|
|
|
239
|
|
|
227
|
Oil
|
|
|
2
|
|
|
1
|
|
|
|
|
|
|
Total
|
|
|
241
|
|
|
228
|
|
|
Acreage
The following table sets forth certain information with respect
to our developed and undeveloped acreage as of May 31, 2007.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Developed
|
|
Undeveloped
|
|
Total
|
|
|
Gross
|
|
Net
|
|
Gross
|
|
Net
|
|
Gross
|
|
Net
|
|
|
Ozona Northeast
|
|
|
28,000
|
|
|
27,000
|
|
|
17,000
|
|
|
17,000
|
|
|
45,000
|
|
|
44,000
|
Cinco Terry
|
|
|
2,000
|
|
|
1,000
|
|
|
20,000
|
|
|
7,000
|
|
|
22,000
|
|
|
8,000
|
Western Kentucky (Boomerang)
|
|
|
|
|
|
|
|
|
74,000
|
|
|
44,000
|
|
|
74,000
|
|
|
44,000
|
Northern New Mexico
(El Vado East)
|
|
|
|
|
|
|
|
|
90,000
|
|
|
81,000
|
|
|
90,000
|
|
|
81,000
|
|
|
|
|
|
|
Total
|
|
|
30,000
|
|
|
28,000
|
|
|
201,000
|
|
|
149,000
|
|
|
231,000
|
|
|
177,000
|
|
|
Drilling
activity
The following table sets forth information on our drilling
activity during the periods indicated. The information should
not be considered indicative of future performance, nor should
it be
73
assumed that there is necessarily any correlation between the
number of productive wells drilled, quantities of reserves found
or economic value.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year ended
December 31,
|
|
Three months
ended
|
|
|
2004
|
|
2005
|
|
2006
|
|
March 31,
2007
|
|
|
Gross
|
|
Net
|
|
Gross
|
|
Net
|
|
Gross
|
|
Net
|
|
Gross
|
|
Net
|
|
|
Development:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Productive
|
|
|
46.0
|
|
|
42.2
|
|
|
115.0
|
|
|
106.6
|
|
|
81.0
|
|
|
77.3
|
|
|
9.0
|
|
|
9.0
|
Non-productive
|
|
|
1.0
|
|
|
1.0
|
|
|
7.0
|
|
|
5.8
|
|
|
6.0
|
|
|
6.0
|
|
|
|
|
|
|
Exploratory:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Productive
|
|
|
|
|
|
|
|
|
1.0
|
|
|
0.5
|
|
|
2.0
|
|
|
1.6
|
|
|
|
|
|
|
Non-productive
|
|
|
|
|
|
|
|
|
2.0
|
|
|
1.0
|
|
|
|
|
|
|
|
|
|
|
|
|
Total:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Productive
|
|
|
46.0
|
|
|
42.2
|
|
|
116.0
|
|
|
107.1
|
|
|
83.0
|
|
|
78.9
|
|
|
9.0
|
|
|
9.0
|
Non-productive
|
|
|
1.0
|
|
|
1.0
|
|
|
9.0
|
|
|
6.8
|
|
|
6.0
|
|
|
6.0
|
|
|
|
|
|
|
|
|
Hedging
activity
Derivative
instruments and hedging activities
We enter into financial swaps and collars to hedge future gas
and oil production to mitigate portions of the risk of market
price fluctuations.
All derivative instruments are recorded on the balance sheet at
fair value. Changes in the derivatives fair value are
currently recognized in the statement of operations unless
specific hedge accounting criteria are met. For qualifying
cash-flow hedges, the gain or loss on the derivative is deferred
in accumulated other comprehensive income (loss) to the extent
the hedge is effective. The ineffective portion of the hedge is
recognized immediately in the statement of operations. Gains and
losses on hedging instruments included in cumulative other
comprehensive income (loss) are reclassified to oil and gas
sales revenue in the period that the related production is
delivered. Derivative contracts that do not qualify for hedge
accounting treatment are recorded as derivative assets and
liabilities at fair value in the balance sheet, and the
associated unrealized gains and losses are recorded as current
income or expense in the statement of operations.
Historically, we have not designated our derivative instruments
as cash-flow hedges. We record our open derivative instruments
at fair value on our combined balance sheets as either
unrealized gains or losses on commodity derivatives. We record
changes in such fair value in earnings on our combined
statements of operations under the caption entitled change
in fair value of commodity derivatives.
Title to
properties
Our properties are subject to customary royalty interests, liens
incident to operating agreements, liens for current taxes and
other burdens, including other mineral encumbrances and
74
restrictions. We do not believe that any of these burdens
materially interfere with our use of the properties in the
operation of our business.
We believe that we have generally satisfactory title to or
rights in all of our producing properties. As is customary in
the oil and gas industry, we make a general investigation of
title at the time we acquire undeveloped properties. We receive
title opinions of counsel before we commence drilling
operations. We believe that we have satisfactory title to all of
our other assets. Although title to our properties is subject to
encumbrances in certain cases, we believe that none of these
burdens will materially detract from the value of our properties
or from our interest therein or will materially interfere with
our use of the properties in the operation of our business.
Competition
The oil and gas industry is highly competitive, and we compete
with a substantial number of other companies that have greater
resources. Many of these companies explore for, produce and
market oil and gas, carry on refining operations and market the
resultant products on a worldwide basis. The primary areas in
which we encounter substantial competition are in locating and
acquiring desirable leasehold acreage for our drilling and
development operations, locating and acquiring attractive
producing oil and gas properties, and obtaining purchasers and
transporters of the oil and gas we produce. There is also
competition between producers of oil and gas and other
industries producing alternative energy and fuel. Furthermore,
competitive conditions may be substantially affected by various
forms of energy legislation
and/or
regulation considered from time to time by the United States
government. However, it is not possible to predict the nature of
any such legislation or regulation that may ultimately be
adopted or its effects upon our future operations. Such laws and
regulations may, however, substantially increase the costs of
exploring for, developing or producing gas and oil and may
prevent or delay the commencement or continuation of a given
operation. The effect of these risks cannot be accurately
predicted.
Regulation
The oil and gas industry in the United States is subject to
extensive regulation by federal, state and local authorities. At
the federal level, various federal rules, regulations and
procedures apply, including those issued by the United States
Department of Interior as noted above, and the United States
Department of Transportation (Office of Pipeline Safety). At the
state and local level, various agencies and commissions regulate
drilling, production and midstream activities. These federal,
state and local authorities have various permitting, licensing
and bonding requirements. Various remedies are available for
enforcement of these federal, state and local rules, regulations
and procedures, including fines, penalties, revocation of
permits and licenses, actions affecting the value of leases,
wells or other assets, and suspension of production. As a
result, there can be no assurance that we will not incur
liability for fines and penalties or otherwise subject us to the
various remedies as are available to these federal, state and
local authorities. However, we believe that we are currently in
material compliance with these federal, state and local rules,
regulations and procedures.
75
Transportation
and sale of gas
The Federal Energy Regulation Commission, or FERC,
regulates interstate gas pipeline transportation rates and
service conditions. Although the FERC does not regulate gas
producers such as us, the agencys actions are intended to
foster increased competition within all phases of the gas
industry. To date, the FERCs pro-competition policies have
not materially affected our business or operations. It is
unclear what impact, if any, future rules or increased
competition within the gas industry will have on our gas sales
efforts.
The FERC or other federal or state regulatory agencies may
consider additional proposals or proceedings that might affect
the gas industry. In addition, new legislation may affect the
industries and markets in which we operate. We cannot predict
when or if these proposals will become effective or any effect
they may have on our operations. We do not believe, however,
that any of these proposals will affect us any differently than
other gas producers with which we compete.
Regulation of
production
Oil and gas production is regulated under a wide range of
federal and state statutes, rules, orders and regulations. State
and federal statutes and regulations require permits for
drilling operations, drilling bonds and reports concerning
operations. The states in which we own and operate properties
have regulations governing conservation matters, including
provisions for the unitization or pooling of oil and gas
properties, the establishment of maximum rates of production
from oil and gas wells and the regulation of the spacing,
plugging and abandonment of wells. Also, each state generally
imposes an ad valorem, production or severance tax with respect
to production and sale of oil, gas and gas liquids within its
jurisdiction.
Environmental
regulations
The exploration for and development of oil and gas and the
drilling and operation of wells, fields and gathering systems
are subject to extensive federal, state and local laws and
regulations governing environmental protection as well as
discharge of materials into the environment. These laws and
regulations may, among other things:
|
|
|
require the acquisition of various permits before drilling
commences;
|
|
|
require the installation of expensive pollution control
equipment;
|
|
|
restrict the types, quantities and concentration of various
substances that can be released into the environment in
connection with oil and gas drilling production, transportation
and processing activities;
|
|
|
suspend, limit or prohibit construction, drilling and other
activities in certain lands lying within wilderness, wetlands
and other protected areas; and
|
|
|
require remedial measures to mitigate and remediate pollution
from historical and ongoing operations, such as the closure of
waste pits and plugging of abandoned wells.
|
These laws, rules and regulations may also restrict the rate of
oil and gas production below the rate that would otherwise be
possible. The regulatory burden on the oil and gas industry
increases the cost of doing business in the industry and
consequently affects profitability.
76
Governmental authorities have the power to enforce compliance
with environmental laws, regulations and permits, and violations
are subject to injunction, as well as administrative, civil and
criminal penalties. The effects of existing and future laws and
regulations could have a material adverse impact on our
business, financial condition and results of operations. While
we believe that we are in substantial compliance with existing
environmental laws and regulations and that continued compliance
with current requirements would not have a material adverse
effect on us, there is no assurance that this will continue in
the future.
The following is a summary of some of the existing laws, rules
and regulations to which our business operations are subject.
Comprehensive
Environmental Response, Compensation and Liability Act
The Comprehensive Environmental Response, Compensation and
Liability Act of 1980, or CERCLA, also known as the Superfund
law, imposes strict, and under certain circumstances, joint and
several liability, on classes of persons who are considered to
be responsible for the release of a hazardous substance into the
environment. These persons include the owner or operator of the
site where the release occurred, and anyone who disposed or
arranged for the disposal of a hazardous substance released at
the site. Under CERCLA, such persons may be subject to strict,
joint and several liabilities for the costs of cleaning up the
hazardous substances that have been released into the
environment, for damages to natural resources and for the costs
of certain health studies. In addition, it is not uncommon for
neighboring landowners and other third-parties to file claims
for personal injury and property damage allegedly caused by the
hazardous substances released into the environment. While we
generate materials in the course of our operations that may be
regulated as hazardous substances, we have not received
notification that we may be potentially responsible for cleanup
costs under CERCLA.
Waste
handling
The Resource Conservation and Recovery Act, or RCRA, and
comparable state statutes, regulate the generation,
transportation, treatment, storage, disposal and cleanup of
hazardous and non-hazardous wastes. Under the auspices of the
Federal Environmental Protection Agency, or EPA, the individual
states administer some or all of the provisions of RCRA,
sometimes in conjunction with their own, more stringent
requirements. Drilling fluids, produced waters and most of the
other wastes associated with the exploration, development,
exploitation and production of oil or gas are currently
regulated under RCRAs non-hazardous waste provisions.
However, it is possible that certain oil and gas exploration and
production wastes now classified as non-hazardous could be
classified as hazardous wastes in the future. Any such change
could result in an increase in our operating expenses, which
could have a material adverse effect on our results of
operations and financial position.
We currently own or lease, and have in the past owned or leased,
properties that for many years have been used for oil and gas
exploration, production and development activities. Although we
used operating and disposal practices that were standard in the
industry at the time, petroleum hydrocarbons or wastes may have
been disposed of or released on, under or from the properties
owned or leased by us or on, under or from other locations where
such wastes have been taken for disposal. In addition, some of
these properties have been operated by third parties whose
treatment and disposal or release of petroleum hydrocarbons and
wastes was not under our control. These properties and the
materials disposed or released on, at, under or from them may be
subject to CERCLA, RCRA and analogous state laws. Under such
laws, we could be
77
required to remove or remediate previously disposed wastes or
contamination, or to perform remedial activities to prevent
future contamination.
Air
emissions
The federal Clean Air Act and comparable state laws regulate
emissions of various air pollutants through air emissions
permitting programs and the imposition of other requirements. In
addition, the EPA has developed, and continues to develop,
stringent regulations governing emissions of hazardous and toxic
air pollutants at specified sources. These regulatory programs
may require us to obtain permits before commencing construction
on a new source of air emissions and may require us to reduce
emissions at existing facilities. As a result, we may be
required to incur increased capital and operating costs.
Additionally, federal and state regulatory agencies can impose
administrative, civil and criminal penalties for non-compliance
with air permits or other requirements of the federal Clean Air
Act and analogous state laws and regulations.
Water
discharges
The Federal Water Pollution Control Act, also known as the Clean
Water Act, and analogous state laws, impose restrictions and
strict controls with respect to the discharge of pollutants,
including spills and leaks of oil and other substances into
regulated waters, including wetlands. The discharge of
pollutants into regulated waters is prohibited, except in
accordance with the terms of a permit issued by the EPA or an
analogous state agency. Federal and state regulatory agencies
can impose administrative, civil and criminal penalties for
non-compliance with discharge permits or other requirements of
the Clean Water Act and analogous state laws and regulations.
Other laws and
regulations
In February 2005, the Kyoto Protocol to the United Nations
Framework Convention on Climate Change entered into force.
Pursuant to the Protocol, adopting countries are required to
implement national programs to reduce emissions of certain
gases, generally referred to as greenhouse gases, which are
suspected of contributing to global warming. The United States
is not currently a participant in the Protocol. However,
Congress has enacted legislation directed at reducing greenhouse
gas emissions and the EPA may be required to regulate greenhouse
gas emissions, and many states have already adopted legislation
or undertaken regulatory initiatives addressing greenhouse gas
emissions from various sources. The oil and gas exploration and
production industry is a direct source of certain greenhouse gas
emissions, namely carbon dioxide and methane, and future
restrictions on such emissions would likely adversely impact our
future operations, results of operations and financial
condition. At this time, although it is not possible to
accurately estimate how potential future laws or regulations
addressing greenhouse gas emissions would impact our business,
passage of such laws or regulation affecting areas in which we
conduct business could have an adverse effect on our operations.
Employees
At May 31, 2007, we had 16 full-time employees. None
of our employees is represented by a labor union or covered by
any collective bargaining agreement. We believe that our
relations with our employees are satisfactory.
78
Legal
proceedings
From time to time, we are subject to legal proceedings and
claims that arise in the ordinary course of business. Like other
gas and oil producers and marketers, our operations are subject
to extensive and rapidly changing federal and state
environmental, health and safety and other laws and regulations
governing air emissions, wastewater discharges, and solid and
hazardous waste management activities.
As of the date of this prospectus, we are not aware of any
pending or overtly threatened legal actions that we believe,
based on our experience to date, would have a material adverse
impact on our business, financial position or results of
operations.
Insurance
matters
As is common in the oil and gas industry, we will not insure
fully against all risks associated with our business either
because such insurance is not available or because premium costs
are considered prohibitive. A loss not fully covered by
insurance could have a materially adverse effect on our
financial position or results of operations.
79
Management
Executive
officers and directors
The following table sets forth the names, ages and positions of
our executive officers and directors as of May 31, 2007.
|
|
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Name
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Age
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Position(s)
held
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J. Ross Craft
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50
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President, Chief Executive Officer
and Class III Director
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Steven P. Smart
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52
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Executive Vice President and Chief
Financial Officer
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J. Curtis Henderson
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44
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Executive Vice President and
General Counsel
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Glenn W. Reed
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55
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Senior Vice
PresidentOperations
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Ralph P. Manoushagian
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56
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Senior Vice PresidentLand
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Bryan H. Lawrence
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64
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Chairman, Class III Director
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James H. Brandi
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59
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Class II Director
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James C. Crain
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59
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Class II Director
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Sheldon B. Lubar
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78
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Class I Director
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Christopher J. Whyte
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50
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Class I Director
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J. Ross Craft
has been our President and Chief Executive
Officer since our inception in September 2002. Before Approach,
Mr. Craft co-founded Athanor Resources Inc., an
international exploration and production company with operations
in the United States and Tunisia, in 1998 and was its Executive
Vice President from 1998 until its merger with Nuevo Energy
Company in September 2002. From 1988 to 1997, Mr. Craft
served in various positions with American Cometra Inc., an
independent exploration and production company with operations
in the United States, including Vice PresidentOperations
from 1995 to 1997. American Cometra was sold in two parts, to
Range Resources in 1995 and Pioneer Natural Resources in 1997.
Mr. Craft has 27 years of experience the oil and gas
industry. Mr. Craft, who holds a B.S. in Petroleum
Engineering from Texas A&M University, is a registered
Professional Engineer licensed in the State of Texas. In
addition to membership in the Society of Petroleum Engineers,
Mr. Craft is also a member of the Texas Oil and Gas
Association and Independent Petroleum Association of America.
Mr. Craft has served on the board of the Fort Worth
chapter of the Society of Petroleum Engineers as well as on the
board of the Fort Worth Petroleum Engineers Club where his
last position was President. Mr. Craft is the
brother-in-law
of J. Curtis Henderson, our Executive Vice President and General
Counsel.
Steven P. Smart
has been our Treasurer since our
inception in September 2002. Mr. Smart was named Vice
PresidentFinance in August 2005, and Executive Vice
President and Chief Financial Officer in June 2007. From 2000 to
2002, Mr. Smart was Controller and Treasurer of Prize
Energy Corp., a public exploration and production company. From
1998 to 2000, Mr. Smart was a Senior Manager in the Energy
Industry group at Arthur Andersen LLP. Prior to 2000,
Mr. Smart served in senior executive financial positions
with several public and private oil and gas companies, including
Magnum Hunter Resources Inc. and Saxon Oil Co. Mr. Smart
began his career in public accounting with Deloitte &
Touche (formerly Touche Ross). Mr. Smart has more than
30 years of experience in both public and private companies
in the oil and gas industry. Mr. Smart, who holds a B.B.A.
in Accounting from Angelo State University, is a Certified
Public Accountant with an active license.
80
J. Curtis Henderson
joined us in February 2007 as
Executive Vice President and General Counsel. From 2005 to 2007,
Mr. Henderson served as President and Chief Executive
Officer of Coterie Capital Partners, Ltd., a private equity
partnership in Dallas, Texas. From 1998 to 2005,
Mr. Henderson served as General Counsel of Nucentrix
Broadband Networks, Inc., a public broadband wireless
telecommunications company based in Dallas. While he was at
Nucentrix, Mr. Henderson oversaw the sale of that company
to an affiliate of Nextel Communications Inc. under
Section 363 of the United States Bankruptcy Code in 2004.
Mr. Henderson has over 19 years experience in public
and private securities, mergers and acquisitions, corporate
finance and regulatory affairs. Mr. Henderson holds a B.A.
in Political Science from Austin College and a J.D. from
Washington and Lee University School of Law. Mr. Henderson
is the
brother-in-law
of J. Ross Craft, our Chief Executive Officer and President.
Glenn W. Reed
has been our Senior Vice
PresidentOperations since June 2007. Mr. Reed served
as our Vice PresidentOperations from our inception in
September 2002 to June 2007. Mr. Reed was Manager of
Operations for Athanor Resources Inc. from 1999 to 2002, where
he was responsible for petroleum engineering and operations
before Athanor was sold to Nuevo Energy Company in September
2002. From 1988 to 1999, Mr. Reed supervised operations for
American Cometra. Mr. Reed, who holds a B.S. in Petroleum
Engineering from Texas Tech University, is a registered
Professional Engineer licensed in Texas and has 28 years of
experience in the oil and gas industry.
Ralph P. Manoushagian
has been our Senior Vice
PresidentLand since June 2007. Mr. Manoushagian
joined us in 2004 as Land Manager. In 2003,
Mr. Manoushagian worked as an independent landman. From
2001 to 2003, Mr. Manoushagian was the President of Hudco
Fuels, a privately owned fuel distributorship.
Mr. Manoushagian has been an active landman and oil and gas
operator for 30 years. Mr. Manoushagian, who holds a
B.B.A. in Finance from the University of North Texas, has been a
Certified Professional Landman since 1988. Mr. Manoushagian
is a director of the First Financial Bank of Southlake, Texas.
He previously served as a director and Vice President of the
Texas Independent Producers and Royalty Owners and as a director
of the Texas Alliance of Energy Producers.
Bryan H. Lawrence
has been a member of our board of
directors since 2002. Mr. Lawrence is a founder and Senior
Manager of Yorktown Partners LLC, the manager of the Yorktown
group of investment partnerships, which make investments in
companies in the energy industry. The Yorktown partnerships were
formerly affiliated with the investment firm of Dillon,
Read & Co. Inc., where Mr. Lawrence had been
employed since 1966, serving as a Managing Director until the
merger of Dillon Read with SBC Warburg in September 1997.
Mr. Lawrence also serves as a director of Crosstex Energy,
Inc. and Crosstex Energy GP, LLC, midstream natural gas
companies; Hallador Petroleum Company, an independent company
engaged in the production of coal and the exploration and
production of oil and natural gas; the general partner of Star
Gas Partners, L.P., a home heating oil distributor and services
provider; Winstar Resources, a public Canadian oil and gas
company; Ellora Energy Inc., an independent oil and gas company;
and certain non-public companies in the energy industry in which
Yorktown partnerships hold equity interests. Mr. Lawrence
is a graduate of Hamilton College and also has an M.B.A. from
Columbia University.
James H. Brandi
joined us as a director in June 2007.
Since November 2005, Mr. Brandi has been a partner at Hill
Street Capital, a private investment and financial advisory
firm. From 2000 until November 2005, Mr. Brandi was a
Managing Director at UBS Securities, LLC, where he was the
Deputy Global Head of the Energy and Power Group. Prior to 2000,
Mr. Brandi was a Managing Director at Dillon,
Read & Co. Inc. and later its successor firm, UBS
Warburg, concentrating on
81
transactions in the energy and consumer goods areas.
Mr. Brandi serves on the boards of Energy East Corporation,
a utility holding company, and Armstrong Land Company, LLC, a
coal reserves owning company. Mr. Brandi is a trustee of
The Kenyon Review and a former trustee of Kenyon College.
Mr. Brandi holds a B.A. in History from Yale University and
an M.B.A. from Harvard Business School and attended Columbia Law
School as a Harlan Fiske Stone Scholar.
James C. Crain
joined us as a director in June 2007.
Mr. Crain has been involved in the energy industry for over
30 years, both as an attorney and as an executive officer.
Since 1984, Mr. Crain has been an officer of Marsh
Operating Company, an investment management company focusing on
energy investing, including his current position of President
which he has held since 1989. Mr. Crain has served as
general partner of Valmora Partners, L.P., a private investment
partnership that invests in the oil and gas sector, among
others, since 1997. Prior to joining Marsh in 1984,
Mr. Crain was a partner in the law firm of
Jenkens & Gilchrist, where he headed the firms
energy section. Mr. Crain currently is a director of
Crosstex Energy, Inc. and Crosstex Energy GP, LLC, midstream
natural gas companies, and GeoMet, Inc., a coalbed methane
natural gas exploration and production company. Mr. Crain
holds a B.B.A., an M.P.A. and a J.D. from the University of
Texas at Austin.
Sheldon B. Lubar
joined us as a director in June 2007.
Mr. Lubar has been Chairman of the Board of
Lubar & Co. Incorporated, a private investment and
venture capital firm he founded, since 1977. He was Chairman of
the Board of Christiana Companies, Inc., a logistics and
manufacturing company, from 1987 until its merger with
Weatherford International in 1995. Mr. Lubar is currently a
director of Crosstex Energy, Inc. and Crosstex Energy GP, LLC,
midstream natural gas companies; Weatherford International,
Inc., an energy services company; Ellora Energy Inc., an
independent oil and gas company; and the general partner of Star
Gas Partners, L.P., a home heating oil distributor and services
provider. Mr. Lubar previously held governmental
appointments under three United States Presidents, including
Commissioner of the White House Conference on Small Business
from 1979 to 1980 under President Carter, Assistant Secretary,
Housing Production and Mortgage Credit, Department of Housing
and Urban Development, Commissioner of the Federal Housing
Administration and Director of the Federal National Mortgage
Association from 1973 to 1974 under Presidents Nixon and Ford.
Mr. Lubar is a past president of the Board of Regents of
the University of Wisconsin System. Mr. Lubar holds a B.S.
in Business Administration and a J.D. from the University of
WisconsinMadison. Mr. Lubar was awarded an honorary
Doctor of Commercial Science degree from the University of
WisconsinMilwaukee.
Christopher J. Whyte
has been a member of our board of
directors since June 2007. Mr. Whyte has been President,
Chief Executive Officer and a director of PetroSantander Inc.,
an affiliate of Yorktown Partners LLC which owns and operates
oil and gas production in Colombia, Kansas and Brazil, since
1995. Mr. Whyte holds a B.A. from the University of
Pittsburgh.
Board of
directors; committees of the board
Our board of directors currently consists of six directors,
Messrs. Brandi, Craft, Crain, Lawrence, Lubar and Whyte.
Our restated certificate of incorporation and restated bylaws
provide for a classified board of directors consisting of three
classes of directors, each serving staggered three-year terms.
As a result, stockholders will elect a portion of our board of
directors each year. Class I directors terms will
expire at the annual meeting of stockholders to be held in 2008,
Class II directors terms will expire at the annual
meeting of stockholders to be held in 2009 and Class III
directors terms will expire at the annual meeting of
stockholders to be held in 2010. Presently, the Class I
directors are Messrs. Lubar and Whyte, the Class II
directors are
82
Messrs. Brandi and Crain and the Class III directors
are Messrs. Craft and Lawrence. At each annual meeting of
stockholders held after the initial classification, the
successors to directors whose terms will then expire will be
elected to serve from the time of election until the third
annual meeting following election. The division of our board of
directors into three classes with staggered terms may delay or
prevent a change of our management or a change in control. See
Description of capital stockAnti-takeover effects of
provisions of Delaware Law, our restated certificate of
incorporation and restated bylawsClassified board.
In addition, our restated bylaws provide that the authorized
number of directors, which shall constitute the whole board of
directors, may be changed by resolution duly adopted by our
board of directors. Any additional directorships resulting from
an increase in the number of directors will be distributed among
the three classes so that, to the extent possible, any
newly-created directorships shall be added to those classes
whose terms of office are to expire at the latest dates
following such increase. Vacancies and newly-created
directorships may be filled by the affirmative vote of a
majority of our directors then in office, even if less than a
quorum.
Our board of directors has established an Audit Committee and a
Compensation and Nominating Committee. As a controlled company
as defined by the NASDAQ Marketplace Rules, we are not required
to have separate compensation and nominating committees.
Messrs. ,
and
serve on the Audit Committee of our board of directors. Each of
Messrs. , and
is independent under the listing standards of
National Association of Securities Dealers, Inc. and SEC rules.
In addition, our board of directors has determined that
Mr.
is an audit committee financial expert, as defined
under the rules of the SEC. The Audit Committee recommends to
our board of directors the independent public accountants to
audit our financial statements and oversees the annual audit.
The Committee also approves any other services provided by
public accounting firms. The Audit Committee provides assistance
to our board of directors in fulfilling its oversight
responsibility to the stockholders, the investment community and
others relating to the integrity of our financial statements,
our compliance with legal and regulatory requirements, the
independent auditors qualifications and independence and
the performance of our internal audit function, as applicable.
The Committee oversees our system of disclosure controls and
procedures and system of internal controls regarding financial,
accounting, legal compliance and ethics that management and our
board of directors have established. In doing so, it is the
responsibility of the Committee to maintain free and open
communication between the Committee and our independent
auditors, the internal accounting function and our management.
Messrs. and
serve on the Compensation and Nominating Committee of our board
of directors. This Committee nominates candidates to serve on
our board of directors and approves director compensation. The
Committee is also responsible for monitoring a process to assess
board effectiveness, developing and implementing our corporate
governance guidelines and taking a leadership role in shaping
our corporate governance. See Executive
compensationOur Compensation and Nominating
Committee for a description of the additional duties of
the Compensation and Nominating Committee.
83
Indemnification
Our restated certificate of incorporation and restated bylaws
provide indemnification rights to the members of our board of
directors. Additionally, we will enter into separate
indemnification agreements with the members of our board of
directors to provide additional indemnification benefits,
including the right to receive in advance reimbursements for
expenses incurred in connection with a defense for which the
director is entitled to indemnification.
Compensation
committee interlocks and insider participation
None of our executive officers serves as a member of the board
of directors or compensation committee of any entity that has
one or more of its executive officers serving as a member of our
board of directors or Compensation and Nominating Committee.
84
Executive
compensation
Compensation
discussion and analysis
This compensation discussion describes the material elements of
compensation awarded to, earned by or paid to our Chief
Executive Officer, Chief Financial Officer and our three other
most highly compensated executive officers, each as named in the
tables below. We refer to all of these officers as named
executive officers. While this compensation discussion
focuses primarily on the information contained in the following
tables and related footnotes, as well as the narrative relating
to the last completed fiscal year, we also describe compensation
actions taken before or after the last completed fiscal year to
the extent that such discussion enhances the understanding of
our executive compensation disclosure.
We believe our success depends on the continued contributions of
our named executive officers. Our executive compensation
programs are designed with the philosophy of attracting,
motivating and retaining experienced and qualified executive
officers and directors with compensation that is consistent with
comparable public companies and that recognizes individual merit
and overall business results. Our policies are also intended to
support the attainment of our strategic objectives by tying the
interests of our executive officers with those of our
stockholders through operational and financial performance goals
and equity-based compensation.
The principal elements of our executive compensation programs
are base salary, annual cash incentives, long-term equity
incentives in the form of stock options and stock awards, as
well as other benefits and perquisites. The other benefits and
perquisites provided to our executive officers consist of life,
disability and health insurance benefits, a qualified 401(k)
savings plan, paid vacation and holidays, automobile allowances
and reimbursement for certain club membership dues, cell phone
expenses, professional association dues and fees, and continuing
professional educational programs. Our salary and benefits are
intended to be competitive with similarly situated companies and
our objective is to position the aggregate of these elements at
a level that is commensurate with our size and sustained
performance.
Our Compensation
and Nominating Committee
The Compensation and Nominating Committee of our board of
directors is responsible for the approval, evaluation and
oversight of all of our compensation plans, policies and
programs. The primary purpose of the Compensation and Nominating
Committee is to assist our board of directors in establishing
and implementing our compensation policies and monitoring our
compliance with such policies. The members of our Compensation
and Nominating Committee
are
(chairman)
and ,
each of whom is an independent director in accordance with the
NASDAQ Marketplace rules. From time to time, the Compensation
and Nominating Committee may, whenever it deems appropriate,
form and delegate authority to various subcommittees to the
extent authorized by the Compensation and Nominating Committee.
Mr. ,
as chairman of the Committee, is responsible for selecting the
time and place of meetings and the agendas therefor.
The function of the Compensation and Nominating Committee is
more fully described in its charter, which our board of
directors adopted, effective as
of ,
2007. The Compensation and Nominating Committee reviews and
assesses, on an annual basis, the adequacy of the charter and
recommends any proposed changes to our board of directors for
approval.
85
Acting on behalf of the board of directors, the responsibilities
of the Compensation and Nominating Committee include the
following:
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reviewing and making recommendations to our board of directors
with respect to our general compensation policies;
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reviewing and approving our goals and objectives relating to the
compensation of our executive officers, evaluating such
officers performance in light of these goals and
recommending compensation levels to our board of directors based
on these evaluations;
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reviewing market data to assess our position with respect to the
compensation of our executive officers in order to ensure we are
competitive with comparable public companies;
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administering our stock option and restricted stock plans or
other similar plans including selecting to whom grants under any
such plans are made and determining the terms and type of any
such grant;
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recommending to our board of directors the adoption of
amendments to any of our plans and modifying or canceling any
existing grants under such plans;
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reviewing the sufficiency of the shares available for grant
under any of our plans based on our goals for hiring, bonus and
retention grants and assessing our competitive position with
respect to the level of our equity compensation, vesting
schedules and other terms with comparable public companies; and
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preparing the Report of the Compensation and Nominating
Committee to be included in our proxy statement.
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Compensation
program objectives
The objectives of our executive compensation programs are as
follows:
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attract and retain talented and experienced executives;
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motivate and reward executives whose knowledge, skills and
performance are critical to our success;
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align the interests of our executive officers and stockholders
by motivating executive officers to increase stockholder value
and rewarding executive officers when stockholder value
increases;
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provide a competitive compensation package that is weighted
heavily towards pay for performance, and in which total
compensation is primarily determined by company and individual
results and the creation of stockholder value;
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insure fairness among the executive management team by
recognizing the contributions each executive makes to our
success;
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foster a shared commitment among executives by coordinating
their company and individual goals; and
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compensate our executives accordingly to meet our long-term
objectives.
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The Compensation and Nominating Committee will evaluate the
objectives of our executive compensation programs on a regular
basis. In determining the objectives of our executive
86
compensation programs, the Compensation and Nominating Committee
will examine the appropriate matching of compensation to
performance as an individual and as an executive group. The
Compensation and Nominating Committee is responsible for
comparative analysis of our executive compensation plan against
others in the industry to insure that the executive compensation
plans are competitive.
The Compensation and Nominating Committee is responsible for
reviewing and making recommendations to our board of directors
regarding our executive compensation programs. These programs
will be implemented to achieve the objectives to be established
by the Compensation and Nominating Committee for compensating
our executive officers. The Compensation and Nominating
Committee will review our executive compensation programs on an
annual basis to determine if such programs are effective in
achieving the objectives established by the Compensation and
Nominating Committee. Compensation objectives will be
established based upon various measurements of profitability,
share value enhancement and specific transaction conclusion,
both as individuals and as a management group.
To assist management and the Compensation and Nominating
Committee in assessing and determining compensation packages,
the Compensation and Nominating Committee may engage
compensation consultants or consider relevant market
compensation data prepared by such consultants based upon the
specific needs of the Compensation and Nominating Committee. The
Compensation and Nominating Committee will contract with any
consultants directly and will control and direct the work to be
performed.
The Compensation and Nominating Committee will meet outside the
presence of all of our executive officers to consider the
appropriate compensation for our Chief Executive Officer. For
all other named executive officers, the Compensation and
Nominating Committee will meet outside the presence of all
executive officers, except our Chief Executive Officer. Our
Chief Executive Officer will annually review the performance of
each named executive officer with the Compensation and
Nominating Committee and will make recommendations to the
Compensation and Nominating Committee with respect to the
appropriate base salary, payments to be made under our annual
cash incentive plan and the grant of long-term equity incentive
awards. Based in part on these recommendations from our Chief
Executive Officer and the other considerations discussed below,
the Compensation and Nominating Committee will approve the
annual compensation package of each of our executive officers,
other than our Chief Executive Officer. The Compensation and
Nominating Committee will analyze the performance of our Chief
Executive Officer and determine the base salary, payments to be
made under our annual cash incentive plan and the grant of
long-term equity incentive awards. Input or suggestions
applicable to group or individual compensation from other
executive officers will be solicited by the Compensation and
Nominating Committee.
Compensation for each executive officer will be determined by
the Compensation and Nominating Committee by evaluating such
officers performance, our performance and the
officers impact on our performance. Based upon these
evaluations, the Compensation and Nominating Committee will
determine the compensation for each of our executive officers,
consistent with the objectives established by the Compensation
and Nominating Committee.
The Compensation and Nominating Committee intends to establish
specific performance targets that our executive officers must
achieve in order to receive certain types of compensation,
including annual bonuses, base pay increases and performance
awards under our 2007 Stock Incentive Plan, referred to as our
2007 Plan, which is an amendment and restatement of our 2003
Stock Option Plan, referred to as our prior plan. The
performance targets to be established
87
will be designed to serve as accurate indicators of the
executive officers impact on our operational success and
provide specific standards that motivate the officers to perform
in our best interest and in our stockholders best interests.
These targets are expected to include performance measures that
increase the value of the company, such as: net income, EBITDAX,
reserve growth and specific major tasks that need to be
accomplished to insure the financial health of the company. Each
officers individual goals will be set based upon those
activities that they can control.
Our Compensation and Nominating Committee has not adopted any
formal or informal policies or guidelines for allocating
compensation between long-term and currently paid out
compensation, between cash and non-cash compensation or among
different forms of non-cash compensation.
Our executive
compensation programs
Overall, we intend for our executive compensation programs to be
consistent with the objectives and principals set forth above.
The basic elements of our executive compensation programs are
summarized in the table below, followed by a more detailed
discussion of each compensation program.
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Element
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Characteristics
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Purpose
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Base salary
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Competitive to industry
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Attract and retain
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Incentive bonus
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Based upon performance
individually and as an executive group
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To motivate enhanced share value,
short and long term financial growth and stability of the company
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Stock incentive plan awards
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Based upon performance
individually and as an executive group
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To retain and motivate our
executives over a longer term
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Retirement savings opportunity
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Competitive to industry
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Enhance overall compensation
package
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Health and welfare benefits
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Competitive to industry
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Attract and retain
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Other perquisites
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Competitive to industry
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Attract, retain and motivate
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All pay elements are cash-based except for the stock incentive
program, which is an equity-based award. We expect to consider
market pay practices and practices of industry peers in
determining the overall amounts to be paid. Compensation
opportunities for our executive officers, including our named
executive officers, are designed to be competitive with peer
companies. We believe that a substantial portion of each named
executive officers compensation should be in performance
based pay.
In determining whether to increase or decrease compensation to
our executive officers, including our named executive officers,
we intend to take into account annually the changes (if any) in
the market pay levels based on our industry peers, the
contributions made by the executive officer, the performance of
the executive officer, the increases or decreases in
responsibilities and roles of the executive officer, the
business needs of the executive officer, the transferability of
managerial skills to another employer, the relevance of the
executive officers experience to
88
other potential employers and the ability of the executive
officer to assume a more significant role with another
organization.
In general, compensation or amounts realized by executives from
prior compensation from us, such as gains from previously
awarded stock options or options awards, will not be taken into
account in setting other elements of compensation, such as base
pay, incentive bonuses or awards of stock options under our
long-term equity incentive program. With respect to new
executive officers, we take into account their prior base salary
and annual cash incentives, as well as the contributions
expected to be made by the new executive officer, the business
needs and the role of the executive officer with us. We believe
that our executive officers should be fairly compensated each
year relative to market pay levels of our industry peers and the
internal pay levels of our executive officers.
Annual cash
compensation
To attract and retain executives with the ability and the
experience necessary to lead us and deliver strong performance
to our stockholders, we provide a competitive total compensation
package. Base salaries are intended to be competitive with our
industry peers, while total compensation is intended to exceed
that of our industry peers, considering individual performance
and experience, to ensure that each executive is appropriately
compensated.
Base
salary
We intend to review salary ranges and individual salaries for
our executive officers annually. We establish the base salary
for each executive officer based on consideration of pay levels
of our industry peers and internal factors, such as the
individuals performance and experience, and the pay of
others on the executive team.
We consider market pay levels among individuals in comparable
positions with transferable skills within the oil and gas
industry and comparable companies in general industry. When
establishing the base salary of any executive officer, we also
consider business requirements for certain skills, individual
experience and contributions, the roles and responsibilities of
the executive and other factors. We believe competitive base
salary is necessary to attract and retain an executive
management team with the appropriate abilities and experience
required to lead us.
The base salaries paid to our named executive officers are set
forth below in the Summary Compensation Table. See
Summary of compensation.
Annual incentive
bonuses
We provide the opportunity for our named executive officers and
other executives to earn an annual cash incentive award. We
provide this opportunity to attract and retain an appropriate
caliber of talent for the position and to motivate executives to
achieve our annual business goals. We plan to review annual cash
incentive awards for our named executive officers and other
executives annually in January or February to determine award
payments for the last completed fiscal year, as well as to
establish award opportunities for the current fiscal year. The
Compensation and Nominating Committee or the board of directors
may exercise discretion and take into account individual
performance in determining the awards.
No incentive bonuses were paid in 2006. In 2007, the named
executive officers received bonuses to cover out-of-pocket taxes
incurred in 2007 as a result of the sale of their respective
shares of
89
our common stock to us as repayment of their respective
management notes, as follows: J. Ross Craft$356,282;
Steven P. Smart$72,814, Glenn W. Reed$86,851; and
Ralph P. Manoushagian $72,301. See Certain
relationships and related party transactionsOther related
party transactions. In 2007, our board approved a bonus
pool of $1.0 million payable one-half upon the filing of
the registration statement of which this prospectus is a part,
and one-half upon this registration statement being declared
effective, as follows: J. Ross Craft$275,000; Steven P.
Smart$182,500; J. Curtis Henderson$182,500; Glenn W.
Reed$120,000; Ralph P. Manoushagian$120,000; and
other key employees$120,000. Beginning in 2008, we intend
to establish individual performance goals for our executives.
Stock incentive
compensation
We plan to award long-term equity incentive grants to executive
officers, including the named executive officers, as part of our
total compensation package, under our 2007 Plan.
The 2007 Plan allows for the grant of stock options, stock
appreciation rights, restricted stock, restricted stock units,
unrestricted stock awards and other incentive awards. The
primary purpose of the 2007 Plan is to enhance our ability to
attract and retain highly qualified officers, directors, key
employees and other persons, and to motivate such persons to
continue in our service and to expend maximum effort to improve
our business results and earnings, by providing to such persons
an opportunity to acquire or increase a direct proprietary
interest in our operations and future success.
After the closing of this offering, the Compensation and
Nominating Committee will administer the 2007 Plan and in doing
so, the Compensation and Nominating Committee will select
participants to receive awards, determine the types of awards
and the terms and conditions of the awards and interpret the
provisions of the 2007 Plan.
Other
benefits
Retirement
savings opportunity
All employees may participate in our 401(k) Retirement Savings
Plan, or the 401(k) Plan, established in 2003. Each employee may
make before tax contributions of up to 25% of their base salary,
subject to the current Internal Revenue Service limits. We
provide this 401(k) Plan to help our employees save a portion of
their cash compensation for retirement in a tax efficient
manner. We match contributions made by our employees to the
401(k) Plan 100% up to 3% of an employees base salary and
50% from 3% to 5% of an employees base salary. We do not
provide an option for our employees to invest in our stock in
the 401(k) plan.
Health and
welfare benefits
All full-time employees, including our named executive officers,
may participate in our health and welfare benefit programs,
including medical, dental and vision care coverage, disability
insurance and life insurance.
90
Other items of
compensation
Other items of compensation for our named executive officers and
key employees may include automobile allowances, reimbursement
for certain club membership dues, cell phone expenses,
professional association dues and fees and continuing
professional educational programs.
Employment
agreements and other arrangements
We have entered into employment agreements with each of
Messrs. Craft, Reed and Smart. These employment agreements
have an initial term of two years but are automatically extended
for successive one-year terms unless either party gives written
notice within 60 days prior to the end of the term to the
other party that such party desires not to renew the employment
agreement. The employment agreements provide for a minimum
annual base salary of $210,000 for Mr. Craft, $190,000 for
Mr. Smart and $165,000 for Mr. Reed. In 2007, our
board approved an increase in Mr. Crafts annual base
salary to $270,000 and Mr. Smarts annual base salary
to $225,000, effective upon the filing of the registration
statement of which this prospectus is a part, and an increase in
Mr. Reeds annual base salary to $185,000. In
addition, each of Messrs. Craft, Reed and Smart are
eligible to participate in any annual bonus plan applicable to
the executive and approved by the board of directors or the
Compensation and Nominating Committee, in amounts to be
determined by the Compensation and Nominating Committee, based
on criteria established by the Compensation and Nominating
Committee. During the period of employment under these
agreements, each of the employees is entitled to additional
benefits, including reimbursement of business and entertainment
expense, paid vacation and participation in other company
benefits, plans or programs that may be available to other
executive employees of our company.
If any of Mr. Craft, Mr. Reed or Mr. Smart is
terminated for cause, we will be obligated to pay such named
executive officer his base salary then in effect through the
date of his termination, prorated for any partial period of
employment, and we shall have no further obligations to such
named executive officer under his respective employment
agreement. Cause means any of the following: the
willful and continue failure of the named executive officer
substantially to perform his duties under the employment
agreement (other than any such failure resulting from such
employee becoming disabled); the willful engaging by the named
executive officer in misconduct that is materially injurious to
us; any misconduct in the course and scope of the named
executive officers employment, including but not limited
to dishonesty, disloyalty, disorderly conduct, insubordination,
harassment of other employees or third parties, abuse of alcohol
or controlled substances or other violations of our rules; or
any material violation of such named executive officers
employment agreement or a voting and stockholders
agreement (which agreement will terminate immediately prior to
the closing of this offering).
If the employment of Mr. Craft or Mr. Reed is
involuntarily terminated without cause, Mr. Craft or
Mr. Reed, as appropriate, is entitled to continue to
receive his base salary plus benefits for a period of
24 months from the date of termination. If
Mr. Crafts involuntary termination occurs during a
change of control period, he will be deemed to have been
terminated without cause. Additionally, Mr. Craft may
terminate his employment for good reason, which will include our
failure to perform under his employment agreement. If
Mr. Craft terminates his employment for good reason, he is
entitled to a lump sum cash payment equal to 50% of his current
base salary within 20 days of his termination, a lump sum
cash payment equal to 150% of his current based salary within
90 days of his termination and continuation of all
applicable benefits for an additional year following his
termination. If Mr. Smarts employment is
involuntarily terminated
91
without cause, Mr. Smart is entitled to continue to receive
his base salary plus benefits for a period of six months from
the date of termination.
In addition, each of these employment agreements contain
provisions that prohibit, with certain limitations,
Messrs. Craft, Reed and Smart from competing with us;
soliciting any of our customers, vendors or acquisition
candidates; or soliciting or hiring any of our employees or
inducing any of them to terminate their employment with us. This
non-competition restriction with respect to Mr. Craft
continues for a period of (i) one year following
termination of employment if Mr. Craft voluntarily resigns
other than on account of a change of control, or his employment
is terminated with or without cause or (ii) six months if
Mr. Craft terminates his employment for good reason other
than a change of control. This non-competition restriction with
respect to Mr. Reed continues for a period of one year
following termination of employment if Mr. Reed voluntarily
resigns other than on account of a change of control, or his
employment is terminated with or without cause. This
non-competition restriction with respect to Mr. Smart
continues for a period of six months following termination of
employment if Mr. Smart voluntarily resigns other than on
account of a change of control, or his employment is terminated
with or without cause. If any of Messrs. Craft, Reed or
Smart is terminated on account of a change of control, this
non-competition restriction will not apply post-termination.
This offering will not constitute a change of control under
these agreements.
Stock ownership
guidelines
Stock ownership guidelines have not been implemented by the
Compensation and Nominating Committee for our executive
officers. Until recently, our common stock was subject to a
stockholders agreement that limited a stockholders ability
to transfer stock. We will continue to periodically review best
practices and reevaluate our position with respect to stock
ownership guidelines.
Tax deductibility
of executive compensation
Limitations on deductibility of compensation may occur under
Section 162(m) of the Internal Revenue Code, which
generally limits the tax deductibility of compensation paid by a
public company to its Chief Executive Officer and certain other
highly compensated executive officers to $1 million in the
year the compensation becomes taxable to the executive officer.
There is an exception to the limit on deductibility for
performance based compensation that meets certain requirements.
Although deductibility of compensation is preferred, tax
deductibility is not a primary objective of our compensation
programs. We believe that achieving our compensation objectives
set forth above is more important than the benefit of tax
deductibility and we reserve the right to maintain flexibility
in how we compensate our executive officers that may result in
limiting the deductibility of amounts of compensation from time
to time.
Conclusion
We believe the compensation we have provided to each of our
executive officers is reasonable and appropriate to facilitate
the achievement of our operational objectives. The compensation
programs and policies that we have designed effectively
incentivize our executive officers on both a short-term and
long-term basis to perform at a level necessary to achieve these
objectives. The various elements of compensation combine to
align the best interests of our
92
executive officers with the best interests of our stockholders
and our best interests in order to maximize stockholder value.
Summary of
compensation
The following table shows information concerning the annual
compensation for services provided to us by our Chief Executive
Officer, our Chief Financial Officer and our two other most
highly compensated executive officers during 2006.
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Stock
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Option
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All other
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Name
and principal positions
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Year
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Salary
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|
Bonus
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awards
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awards
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compensation(1)
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Total
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J. Ross Craft
President and Chief Executive Officer
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2006
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$
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210,000
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(2)
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$
|
|
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$
|
|
|
$
|
|
|
$
|
29,899
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|
$
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239,899
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Steven P. Smart
Executive Vice President and Chief Financial Officer
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2006
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$
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165,000
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(3)
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$
|
|
|
$
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|
|
$
|
|
|
$
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21,763
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|
$
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186,763
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Glenn W. Reed
Senior Vice President Operations
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2006
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$
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165,000
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(4)
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$
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$
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$
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$
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19,204
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$
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184,204
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Ralph P. Manoushagian
Senior Vice PresidentLand
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2006
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$
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127,000
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(5)
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$
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$
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|
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$
|
|
|
$
|
185
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$
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127,185
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(1)
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All other compensation reported for
Mr. Craft represents a $15,800 matching contribution by our
company to our 401(k) plan, $8,400 in automobile allowance, $855
relating to cell phone expenses, $2,230 relating to club
membership dues, $420 relating professional licenses and fees,
$750 for life insurance premiums and $1,444 relating to
continuing professional educational programs. All other
compensation reported for Mr. Smart represents a $12,200
matching contribution by our company to our 401(k) plan, $6,000
in automobile allowance, $710 relating to cell phone expenses,
$1,119 relating to professional licenses and fees and $1,734 for
continuing professional educations programs. All other
compensation reported for Mr. Reed represents a $7,000
matching contribution by our company to our 401(k) plan, $8,400
in automobile allowance, $1,875 relating to cell phone expenses,
$38 relating to professional licenses and fees, $496 for life
insurance premiums and $1,395 for continuing professional
educations programs. All other compensation reported for
Mr. Manoushagian represents $185 relating to professional
licenses and fees.
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(2)
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In June 2007, the board approved an
increase in Mr. Crafts annual base salary to $270,000
effective upon the filing of the registration statement of which
this prospectus forms a part.
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(3)
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In the first quarter of 2007, the
board increased Mr. Smarts annual base salary to
$190,000. In June 2007, the board approved an increase in
Mr. Smarts annual base salary to $225,000 effective
upon the filing of the registration statement of which this
prospectus forms a part.
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(4)
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In June 2007, the board approved an
increase in Mr. Reeds annual base salary to $185,000.
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(5)
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In June 2007, the board approved an
increase in Mr. Manoushagians annual base salary to
$160,000.
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In February 2007, we hired J. Curtis Henderson to serve as our
Executive Vice President, and General Counsel at an annual base
salary of $190,000. In June 2007, the board approved an increase
in Mr. Hendersons annual base salary to $225,000
effective upon the filing of the registration statement of which
this prospectus forms a part. In connection with his employment,
Mr. Henderson was awarded 21,250 shares of our common
stock as restricted stock, one-third of which will vest upon the
closing of this offering, one-third of which will vest upon the
one-year anniversary of the closing of this offering, and
one-third of which will vest upon the two-year anniversary of
the closing of this offering.
Grants of
plan-based awards
During 2006, we did not make any awards under any plan to our
named executive officers.
93
In June 2007, our board authorized the grant of stock awards
under the 2007 Plan covering 100,000 shares of common stock
(pre-split) to our named executive officers and a member of our
technical team, which grants will become effective upon the
closing of this offering. These stock awards were granted as
follows: J. Ross Craft 30,000 shares; Steven P.
Smart 20,000 shares, J. Curtis
Henderson 20,000 shares; Glenn W.
Reed 10,000 shares; Ralph P.
Manoushagian 10,000 shares; and a technical
team member 10,000 shares. As a related matter,
our board also approved special bonuses to cover out-of-pocket
taxes that will be incurred as a result of the receipt by these
executives of stock awards.
Discussion of
summary compensation and plan-based awards tables
Our executive compensation policies and practices, pursuant to
which the compensation set forth in the Summary Compensation
Table and the grants of Plan Based Awards table was paid or
awarded, are described above under Compensation
discussion and analysis. A summary of certain material
terms of our compensation plans and arrangements is set forth
below.
Description of
the 2007 Plan
The 2007 Plan allows for the grant of stock options, stock
appreciation rights, restricted stock, restricted stock units,
performance awards, unrestricted stock awards and other
incentive awards. The primary purpose of the 2007 Plan is to
enhance our ability to attract and retain highly qualified
officers, directors, key employees and other persons, and to
motivate these persons to continue in our service and to expend
maximum effort to improve our business results and earnings, by
providing to these persons an opportunity to acquire or increase
a direct proprietary interest in our operations and future
success. We have reserved 10% of our outstanding shares of
common stock for grant of awards under the 2007 Plan (which will
be adjusted each year to remain at 10% of outstanding shares of
our common stock), plus all shares of common stock that remain
available for grant of awards under the prior plan, plus shares
of common stock subject to outstanding awards under the prior
plan that later cease to be subject to those awards for any
reason other than those awards having been exercised. In
addition, there are 115,385 shares of common stock
(pre-split) subject to outstanding options under the prior plan
that may be issued under the 2007 Plan.
Administration.
The 2007 Plan provides for
administration by the board of directors or compensation
committee of the board of directors or another committee of the
board of directors designated by the board of directors. Subject
to the terms of the 2007 Plan, the board or the committee may
select participants to receive awards, determine the types of
awards and terms and conditions of awards and interpret
provisions of the 2007 Plan. Currently, the 2007 Plan is
administered by the board of directors but we expect that the
Compensation and Nominating Committee will administer the 2007
Plan after the closing of this offering.
Common stock reserved for issuance under the 2007
Plan.
Our common stock issued or to be issued under the
2007 Plan consists of authorized but unissued shares. If an
award granted under the 2007 Plan expires, is forfeited or
becomes unexercisable for any reason without having been
exercised in full, the undelivered shares of common stock which
were subject to the award shall become available for future
awards under the 2007 Plan.
The maximum number of shares of common stock that may be subject
to incentive stock options granted under the 2007 Plan is
1,100,000. The maximum number of shares of common stock that may
be subject to all awards granted to any one participant each
fiscal year is
94
330,000 shares. The maximum number of shares of common
stock that may be subject to nonqualified stock options and
stock appreciation rights granted to any one participant during
a fiscal year is 330,000. The maximum amount that may be paid in
cash pursuant to performance awards granted to a participant
that are intended to satisfy the qualified performance-based
compensation exception to Section 162(m) of the Internal
Revenue Code is $5,000,000 for each fiscal year during the
applicable performance period.
Adjustments for stock dividends and similar
events.
We may make appropriate adjustments in
outstanding awards and the number of shares available for
issuance under the 2007 Plan, including the individual
limitations on awards, to reflect recapitalizations,
reclassifications, stock spits, reverse splits, stock dividends
and other similar events.
Eligibility.
Awards may be made under the 2007 Plan
to our employees, directors and consultants, including any
employee who is an officer or director, and to any other person
who, in the opinion of the committee, is in a position to make a
significant contribution our success.
Amendment or termination of the 2007 Plan.
Our board
of directors may amend, suspend or terminate the 2007 Plan at
any time and for any reason. The 2007 Plan shall terminate in
any event ten years after the date of its approval by the
stockholders. Amendments to the 2007 Plan will be submitted for
stockholder approval if an amendment increases the maximum
number of shares available under the 2007 Plan (except as
otherwise allowable under the 2007 Plan), changes the
designation or class of persons eligible to receive awards under
the 2007 Plan, or if required by applicable law or by applicable
stock exchange listing requirements. Amendments to limit the
scope of the 2007 Plan or to comply with statutory or regulatory
requirements do not require stockholder approval.
Options.
The 2007 Plan permits the granting of
options to purchase shares of common stock intended to qualify
as incentive stock options under the Internal Revenue Code and
stock options that do not qualify as incentive stock options.
The exercise price of each stock option may not be less than
100% of the fair market value of the common stock on the date of
grant. In the case of certain 10% stockholders who receive
incentive stock options, the exercise price may not be less than
110% of the fair market value of the common stock on the date of
grant. An exception to these requirements is made for options
that we grant in substitution for options held by employees of
companies that we acquire. In such a case, the exercise price is
adjusted to preserve the economic value of the employees
stock option from his or her former employer.
The term of each stock option is fixed at the time of grant and
may not exceed 10 years from the date of grant. The
committee determines at what time or times each option may be
exercised and the period of time, if any, after retirement,
death, disability or termination of employment during which
options may be exercised. Options may be made exercisable in
installments. The exercisability of options may be accelerated
by the committee.
In general, a participant may pay the exercise price of an
option in cash or in cash equivalents, by tendering shares of
common stock having an aggregate fair market value at the time
of exercise equal to the total exercise price, by surrendering a
sufficient portion of the shares with respect to which the
option is exercised having an aggregate fair market value at the
time of exercise equal to the total exercise price, or in a
combination of these forms.
Stock options granted under the 2007 Plan may not be sold,
transferred, pledged or assigned other than by will or under
applicable laws of descent and distribution. However, we may
95
permit in an award agreement the limited transfers of
non-qualified options for the benefit of the family members of
the optionees.
Other awards.
The 2007 Plan permits the granting of
the following additional types of awards:
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shares of unrestricted stock, which are shares of common stock
issued at no cost or for a purchase price and are free from any
transferability and forfeiture restrictions;
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shares of restricted stock, which are shares of common stock
subject to transferability restrictions and a substantial risk
of forfeiture;
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restricted stock units, which constitute a promise to transfer
common stock or an equivalent value in cash in the future;
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dividend equivalent rights with respect to restricted stock
units, which are rights entitling the recipient to receive
either payments or credits of cash or additional restricted
stock units equal in amount to the dividends that would be paid
on the common stock subject to the restricted stock units;
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stock appreciation rights, which are rights to receive a number
of shares or, in the discretion of the committee, an amount in
cash or a combination of shares and cash, based on the increase
in the fair market value of the shares underlying the rights
during a specified period of time;
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performance awards, ultimately payable in common stock or cash
(or a combination), as determined by the committee. Performance
awards are conditioned upon the level of achievement of one or
more stated performance goals over a specified performance
period that is not shorter than one year. An award agreement
will specify the amount, or a formula for determining the
amount, that may be earned under the performance award, the
performance criteria and level of achievement versus the
performance criteria that will determine the amount payable
under the performance award, and the performance period over
which performance is measured. Awards to individuals who are
covered employees under Section 162(m) of the Internal
Revenue Code, or who are likely to be covered in the future, may
be designed to qualify as performance-based compensation under
Section 162(m) of the Internal Revenue Code to the extent
that the committee so designates; and
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other incentive awards, which may be payable in common stock,
cash or other property as determined by the committee.
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The committee establishes the terms and conditions of awards.
Change of Control.
In the event of a Change of
Control (as defined in the 2007 Plan), the vesting of all
awards will be accelerated and any performance criteria will be
deemed to be achieved to the maximum extent possible. If there
is a Change of Control and we are not the surviving corporation
(or we survive only as a subsidiary of another corporation),
unless the committee determines otherwise, awards will be
replaced with similar awards of the surviving corporation (or
parent of the surviving corporation). The committee may require
the surrender to us by selected participants of some or all of
the outstanding awards held by such participants, at which time
we will cancel those awards and cause to be paid to each
affected participant a certain amount of cash per share, as
specified in the 2007 Plan.
96
Outstanding
equity awards at fiscal year-end
The following table summarizes the number of securities
underlying outstanding plan awards for each named executive
officer as of December 31, 2006. This table contains
historical numbers and does not reflect the effect of
our
for
stock split, effected in the form of a stock dividend, which
will occur immediately prior to the closing of this offering.
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Option
awards
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Number of
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securities
underlying
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Option
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|
Option
|
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unexercised
options
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exercise
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expiration
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Name
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Exercisable
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Unexercisable
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price
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date
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J. Ross Craft
President and
Chief Executive Officer
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50,964
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$
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10.00
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August 16, 2014
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Steven P. Smart
Executive Vice President and Chief Financial Officer
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9,615
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$
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10.00
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August 16, 2014
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Glenn W. Reed
Senior Vice PresidentOperations
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11,538
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$
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10.00
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August 16, 2014
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Ralph P. Manoushagian
Senior Vice PresidentLand
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9,615
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$
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10.00
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August 16, 2014
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Option
exercises
Our named executive officers did not exercise any stock options
in 2006.
Pension
benefits
We do not have any plan that provides for payments or other
benefits at, following or in connection with retirement, other
than our 401(k) plan.
Non-qualified
deferred compensation
We do not have any plan that provides for the deferral of
compensation on a basis that is not tax qualified.
Director
compensation
Historically, our directors have not received any compensation
for serving on our board, although we did reimburse directors
for expenses incurred in connection with attendance at meetings
of the board of directors. Following this offering, each
non-employee member of our board of directors will receive
compensation for service on our board of directors and
committees thereof. Following this offering, non-employee and
non-Yorktown directors will receive $85,000 per year in shares
of our common stock or cash, at the election of each director,
plus meeting expenses of $1,000 per board and $500 per committee
meeting. The chairman of the Audit Committee will receive $7,500
per year and the chairs of the Compensation and Nominating
Committee will receive $3,500 per year.
Employee directors will not receive compensation for service on
our board of directors. All directors will be reimbursed for
reasonable out-of-pocket expenses incurred in attending
97
meetings of the board or committees and for other reasonable
expenses incurred in connection with service on the board and
any committee.
Potential
payments upon termination or change in control
We have employment agreements with certain of our named
executive officers. Under the terms of the agreements, these
officers receive an annual base salary and are eligible to
participate in an annual bonus plan, to be administered by our
board of directors or otherwise by the Compensation and
Nominating Committee. If any of Mr. Craft, Mr. Reed or
Mr. Smart is terminated for cause, we will be obligated to
pay such named executive officer his base salary then in effect
through the date of termination, prorated for any partial period
of employment, and we shall have no further obligations to such
named executive officer under his respective employment
agreement.
The employment agreement of Messrs. Craft and Reed also
provide that if such officer is terminated by us without cause,
he will be entitled to continue to receive his respective base
salary plus applicable benefits for a period of 24 months
from the date of termination. Mr. Crafts employment
agreement provides that his termination during a change of
control period will be deemed a termination without cause.
Mr. Smarts employment agreement provides that if he
is terminated by us without cause, he will be entitled to
continue to receive his base salary plus applicable benefits for
a period of six months from the date of termination.
Additionally, Mr. Crafts employment agreement
provides that if he terminates his employment for good reason,
he will be entitled to receive severance compensation consisting
of a 50% base salary lump sum payment within 20 days of
termination and a 150% base salary lump sum payment within
90 days of termination.
If Mr. Craft, Mr. Reed or Mr. Smart had been
terminated without cause on December 31, 2006, the
approximate value of the severance benefits, assuming two weeks
of accrued unused vacation time, under the employment agreement
of each such named executive would have been as follows:
Mr. Craft $429,000, Mr. Reed $337,000 and
Mr. Smart $89,000.
For more information about these agreements, please read
Executive compensationOther
benefitsEmployment agreements and other
arrangements. We are not obligated to make any cash
payments to any other named executive officer if their
employment is terminated by us or by the executive. No severance
benefits are provided for any of the named executive officers in
the event of death or disability.
Pursuant to the terms of a restricted stock award agreement
between the company and Mr. Henderson, our Executive Vice
President and General Counsel, in the event of a change of
control of the company (as defined in such award agreement), all
unvested shares of restricted stock held by Mr. Henderson
will fully vest.
This offering will not constitute a change in control of the
company under these agreements.
98
Security
ownership of certain beneficial owners
and management
The following table sets forth certain information regarding the
beneficial ownership of Approach Resources Inc. common stock as
of June 30, 2007, giving effect to the transactions
contemplated by the contribution agreement, for:
(i) each person who, to our knowledge, beneficially owns
more than 5% of our common stock;
(ii) each of our directors and executive officers; and
(iii) all of our executive officers and directors as a
group, before our initial public offering and after the
completion of our initial public offering.
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Shares of Approach
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Shares of Approach
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common stock
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common stock
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beneficially
owned
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beneficially
owned
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prior to
offering(1)
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after
offering(2)
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Name
and address of beneficial owner
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Number
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Percent
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Number
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Percent
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J. Ross Craft(3)(4)
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Steven P. Smart(3)(4)
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J. Curtis Henderson(3)
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Glenn W. Reed(3)(4)
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Ralph P. Manoushagian(3)(4)
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Bryan H. Lawrence(5)(6)
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James H. Brandi(7)
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James C. Crain(8)
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Sheldon B. Lubar(9)(10)
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Christopher J. Whyte(11)
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Yorktown Energy Partners V,
L.P.(5)
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Yorktown Energy Partners VI,
L.P.(5)
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Yorktown Energy Partners VII,
L.P.(5)
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Lubar Equity Fund, LLC(9)
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Neo Canyon Exploration, L.P.(12)
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All officers and directors as a
group (10 persons)(4)
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*
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Less than one percent.
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(1)
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Unless otherwise indicated, all
shares of stock are held directly with sole voting and
investment power.
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(2)
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For purposes of calculating the
percent of the class outstanding held by each owner shown above
with a right to acquire additional shares, the total number of
shares excludes the shares which all other persons have the
right to acquire within 60 days after the date of this
prospectus, pursuant to the exercise of outstanding stock
options and warrants.
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(3)
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Has a principal business address of
c/o Approach
Resources Inc., 6300 Ridglea Place, Suite 1107,
Fort Worth, Texas 76116.
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99
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(4)
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The number of shares beneficially
owned includes the following shares that are subject to options
that are currently exercisable or will become exercisable within
60 days of the date of this prospectus:
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Shares subject
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Name of
beneficial owner
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to
options
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J. Ross Craft
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Steven P. Smart
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Glenn W. Reed
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Ralph P. Manoushagian
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(5)
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Has a principal business address of
410 Park Avenue,
19
th
floor,
New York, New York 10022.
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(6)
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Includes attribution of shares held
by Yorktown Energy Partners V, L.P., Yorktown Energy
Partners VI, L.P. and Yorktown Energy Partners VII, L.P.
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(7)
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Has a principal business address of
126 East 56th Street, New York, New York 10022.
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(8)
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Has a principal business address of
300 Crescent Court, Suite 900, Dallas, Texas 75201.
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(9)
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Has a principal business address of
700 N. Water Street, Suite 1200, Milwaukee,
Wisconsin 53202.
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(10)
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Includes attribution of shares held
by Lubar Equity Fund, LLC.
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(11)
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Has a principal business address of
6363 Woodway, Suite 350, Houston, Texas 77057.
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(12)
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Has a principal business address of
325 North St. Paul, Suite 4300, Dallas, Texas 75201.
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Certain
relationships and related party transactions
The contribution
agreement
Immediately prior to the closing of this offering, Approach
Resources Inc. will acquire all of the outstanding capital stock
of Approach Oil & Gas Inc. and will acquire the 30%
working interest in the Ozona Northeast field that Approach
Resources Inc. does not already own from Neo Canyon
Exploration, L.P. Upon the closing of the transactions
contemplated by the contribution agreement, Neo Canyon
Exploration, L.P. and each of the stockholders of Approach
Oil & Gas Inc. will receive shares of stock in
Approach Resources Inc. in exchange for their respective
contributions. In addition, we have agreed to include up
to shares
of stock in the registration statement of which this prospectus
is a part on behalf of the selling stockholder.
Convertible
notes
On June 25, 2007, Yorktown Energy Partners VII, L.P. and
Lubar Equity Fund, LLC loaned an aggregate of $20,000,000 to
Approach Oil & Gas Inc. under two convertible
promissory notes of $10,000,000 each. These notes bear interest
at a rate of 7.00% per annum and mature on June 25, 2010.
These notes are convertible at the election of the lender into
shares of equity securities of Approach Oil & Gas Inc.
upon the occurrence of certain events and automatically, and
without further action required by any person, convert into
shares of our common stock upon the consummation of this
offering. The number of shares of our common stock to be issued
upon the automatic conversion of these notes will be equal to
the quotient obtained by dividing (a) the outstanding
principal and accrued interest on each respective note by
(b) the initial public offering price per share, less any
underwriting discount per share for the shares of our common
stock that are issued in this offering. The shares of our common
stock issued to Yorktown Energy Partners VII, L.P. and Lubar
Equity Fund, LLC upon such automatic conversion will be entitled
to the same registration rights as those provided to certain
holders of our common stock in connection with the contribution
agreement. The total principal and interest
100
owed under these notes as of June 30, 2007 was $20,023,014,
consisting of $10,011,507 owed to each of Yorktown Energy
Partners VII, L.P. and Lubar Equity Fund, LLC. Yorktown Energy
Partners VII, L.P. is an affiliate of the Yorktown entities, and
Lubar Equity Fund, LLC is an affiliate of Sheldon B. Lubar, who
serves as a member of our board of directors.
Employment and
indemnification agreements
We have entered into employment agreements with certain of our
executive officers. See ManagementExecutive
compensationOther benefitsEmployment agreements and
other arrangements for a detailed description of these
agreements. Additionally, we will enter into indemnification
agreements with our officers and the members of our board of
directors.
Indemnification
of directors and officers
Section 145 of the Delaware General Corporation Law, or the
DGCL, permits indemnification of officers, directors and other
corporate agents under specific circumstances and subject to
specific limitations. Our restated certificate of incorporation
and restated bylaws provide that we will indemnify our directors
and officers to the full extent permitted by the DGCL, including
in circumstances in which indemnification is otherwise
discretionary under Delaware law.
We will enter into indemnity agreements with our directors and
executive officers that provide the maximum indemnity allowed to
directors and executive officers by Section 145 of the
DGCL, as well as certain additional procedural protections. The
indemnity agreements provide that directors are and will be
indemnified to the fullest extent not prohibited by law against
all expenses (including attorneys fees) and settlement
amounts paid or incurred by them in any action or proceeding as
our directors or executive officers, including any action on
account of their services as executive officers or directors of
any other company or enterprise when they are serving in such
capacities at our request, and including any action by us or in
our right. In addition, the indemnity agreements provide for
reimbursement of expenses incurred in conjunction with being a
witness in any proceeding to which the indemnitee is not a
party. We are required to pay in advance of a final disposition
of a proceeding or claim the expenses incurred by the indemnitee
no later than ten days after our receipt of an undertaking by or
on behalf of the indemnitee to repay the amount of the expenses
to the extent that it is ultimately determined that the
indemnitee is not entitled to be indemnified by us. The
indemnity agreements also provide the indemnitee with remedies
in the event that we do not fulfill our obligations under the
indemnity agreements.
Section 102(b)(7) of the DGCL permits a corporation to
provide in its certificate of incorporation that a director of
the corporation will not be personally liable to the corporation
or its stockholders for monetary damages for breach of fiduciary
duty as a director, except for liability (i) for any breach
of the directors duty of loyalty to the corporation or its
stockholders, (ii) for acts or omissions not in good faith
or which involve intentional misconduct or a knowing violation
of law, (iii) for payments of unlawful dividends or
unlawful stock repurchases or redemptions or (iv) for any
transaction from which the director derived an improper personal
benefit. Our certificate of incorporation provides for that
limitation of liability.
We will maintain policies of insurance under which our directors
and officers are insured, within the limits and subject to the
limitations of the policies, against specific expenses in
connection with the defense of, and specific liabilities which
might be imposed as a result of, actions, suits or proceedings
to which they are parties by reason of being or having been
directors or officers.
101
Business
opportunities renunciation
All of our non-employee directors and certain of our
stockholders may from time to time have investments in other
exploration and production companies that may compete with us.
Section 122(17) of the DGCL permits a Delaware corporation,
such as Approach Resources Inc., to renounce in its certificate
of incorporation or by action of its board of directors any
interest or expectancy of the corporation in certain
opportunities, effectively eliminating the ambiguity in a
Delaware corporations ability to do so in advance arising
out of prior Delaware case law. Under corporate law concepts of
fiduciary duty, officers and directors generally have a duty to
disclose to us opportunities that are related to our business
and are generally prohibited from pursuing those opportunities
unless we determine that we are not going to pursue them. Our
restated certificate of incorporation and our Business
Opportunities Agreement provide that so long as any of the
parties to the Business Opportunities Agreement, which we refer
to as Designated Parties, is serving as a member of
our board of directors, we renounce any interest or expectancy
in any business opportunity, transaction or other matter in and
that involves any aspect of the oil and gas exploration,
exploitation, development and production other than:
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any business opportunity that is brought to the attention of a
Designated Party solely in such persons capacity as a
director of our company and with respect to which, at the time
of such presentment, no other Designated Party has independently
received notice or otherwise identified such opportunity; or
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any business opportunity that is identified by a Designated
Party solely through the disclosure of information by or on
behalf of us.
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Thus, for example, a Designated Party may pursue opportunities
in the oil and gas exploration and production industry for their
own account. Our restated certificate of incorporation provides
that the Designated Parties have no obligation to offer such
opportunities to us.
Pursuant to this Business Opportunities Agreement approved by
our board of directors, each of the Designated Parties will not
have a duty to inform us of a business opportunity that he
becomes aware of so long as he did not become aware of the
opportunity solely as a consequence of serving as a member of
our board of directors. Furthermore, the Designated Parties will
each be permitted to pursue that opportunity even if it is
competitive with our business. This business opportunities
agreement does not prohibit us from pursuing any business
opportunity to which we have renounced any interest or
expectancy. It will provide the Designated Parties and their
respective affiliates with some certainty that opportunities
that they independently pursue will not be required to be first
offered to us.
Registration
rights agreement
In connection with the contribution agreement and certain other
transactions, we will enter into a registration rights agreement
with our existing stockholders, pursuant to which we will grant
certain demand and piggyback registration rights.
Under the registration rights agreement, each of Yorktown Energy
Partners V, L.P., Yorktown Energy Partners VI, L.P. and
Yorktown Energy Partners VII, L.P. and the members of our
management team will have the right to require us to file a
registration statement for the public sale of all of the shares
of common stock owned by it or them any time after six months
following the date the SEC declares the registration statement
of which this prospectus forms a part effective. In addition, if
we sell any shares of our common stock in a registered
102
underwritten offering, each of our existing stockholders will
have the right to include his or its shares in that offering.
The underwriters of any such offering will have the right to
limit the number of shares to be included in such sale.
We will pay all expenses relating to any demand or piggyback
registration, except for underwriters or brokers
commission or discounts. The securities covered by the
registration rights agreement will no longer be registrable
under the registration rights agreement if they have been sold
to the public either pursuant to a registration statement or
under Rule 144 promulgated under the Securities Act.
Other related
party transactions
In connection with the formation of Approach Resources Inc. and
subsequent financing transactions, approximately
415,385 shares of our common stock were issued to certain
of our executive officers and other key members of management in
exchange for notes receivable. The notes issued by our executive
officers and other key members of management, including J. Ross
Craft, Steven P. Smart, Glenn W. Reed and Ralph P. Manoushagian,
were full recourse, earned interest at an annual rate of 6.00%,
and matured upon the earlier of (i) December 31, 2008
or, (ii) if earlier, the date upon which the Company or any
successor to the Company registers any class of its securities
under Section 12 of the Securities Exchange Act of 1934, is
required to file periodic reports under Section 15(d) of
the 1934 Act, or files a registration statement under the
Securities Act of 1933, as amended. The note holders repaid
these notes with interest in January 2007 by selling us an
aggregate of 84,550 shares of our common stock in
satisfaction of the management holders aggregate
outstanding indebtedness of $4,184,324. The note holders
received bonuses to cover out-of-pocket taxes incurred in 2007
as a result of the sale of their respective shares of our common
stock to us as repayment for their respective management notes.
On May 10, 2006, we acquired interests in oil and gas
properties in Western Kentucky from Hallador Petroleum Company
for approximately $3.3 million in cash. Hallador Petroleum
Company was owned 32% by Yorktown Energy Partners VI, L.P., an
affiliate of the Yorktown entities, at the time of the
acquisition. The valuation of the New Albany Shale oil and gas
interests held by Hallador Petroleum Company was determined by
arms-length negotiations between us and Hallador. At the time of
the acquisition, Mr. Lawrence was a member of the board of
directors of Hallador and a member of our board of directors.
Under the terms of this agreement, 60 days after we drilled
three exploratory gas wells, Hallador had the option to purchase
a one-third working interest in the project by paying one-third
of the land costs expended by us. In October 2006, Hallador sold
one-half of its rights under this option to T.H. McElvain
Oil & Gas Limited Partnership, an unaffiliated third
party. Drilling began in December 2006. Hallador and McElvain
jointly exercised the option in April 2007, leaving
Halladors net ownership in the project at one-sixth.
Procedures for
review and approval of related person transactions
Before the effective date of the registration statement of which
this prospectus forms a part, we plan to adopt a written code of
conduct. Under this written code of conduct, our executive
officers and directors will not be permitted to enter into any
transactions with us without the approval of either our audit
committee or our board of directors. In approving or rejecting
such proposed transactions, the audit committee or board of
directors, as applicable, will consider the relevant facts and
circumstances available and deemed relevant to the audit
committee or
103
board of directors, as applicable, including the risks, costs,
benefits to the company, the terms of the transactions, the
availability of other sources for comparable services or
products and, if applicable, the impact on a directors
independence. Our audit committee
and/or
board
of directors will approve only those transactions that, in light
of known circumstances, are in, or are not inconsistent with,
our best interests, as our audit committee or board of directors
determines in the good faith exercise of its discretion. We will
designate a compliance officer to generally oversee compliance
with our code of conduct.
All of the transactions described above were entered into before
the adoption of our code of conduct. Instead, their approvals
are as described herein. The contribution agreement and related
transactions were unanimously approved by our board of
directors. The convertible notes were unanimously approved by
our board of directors. The employment agreements, director and
officer indemnification agreements and the business
opportunities agreements were unanimously approved by our board
of directors. The registration rights agreement was unanimously
approved by our board of directors. The Ozona Pipeline and
Hallador transactions were unanimously approved by our board of
directors.
104
Selling
stockholder
The following table sets forth certain information with respect
to the ownership by the selling stockholder of our common stock
as
of ,
2007 and as adjusted to give effect to this offering. To our
knowledge, the selling stockholder will have sole voting and
investment power as to the shares shown. The selling stockholder
is not a director, officer or employee of ours or an affiliate
of such person.
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Shares
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owned prior
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Number of
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Number of
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Shares owned
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to
offering(2)
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shares being
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shares being
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after
offering(3)(4)
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Name
of selling stockholder(1)
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Number
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Percent
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offered(3)
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redeemed
by us
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Number
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Percent
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Neo Canyon Exploration, L.P.
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(1)
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Ownership is determined in
accordance with
Rule 13d-3
under the Securities Exchange Act of 1934.
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(2)
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Based upon an aggregate
of shares
to be outstanding following the consummation of the transactions
described under Certain relationships and related party
transactionsThe contribution agreement.
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(3)
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Assumes no exercise of the
underwriters over-allotment option.
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(4)
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Based upon an aggregate
of shares
to be outstanding following the consummation of the transactions
described under Certain relationships and related party
transactionsThe contribution agreement, the
automatic conversion of notes described under Certain
relationships and related party transactionsConvertible
notes,
our
for
common stock split and this offering.
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105
Description of
capital stock
The following description is based on relevant portions of
the DGCL and on our restated certificate of incorporation and
restated bylaws. This summary is not necessarily complete, and
we refer you to the DGCL, and our restated certificate of
incorporation and restated bylaws for a more detailed
description of the provisions summarized below.
Our authorized capital stock consists of 90,000,000 shares
of common stock, $0.01 par value per share, and
10,000,000 shares of preferred stock, par value $0.01 per
share. Under Delaware law, our stockholders shall not be
personally liable for our debts or obligations except as they
may be liable by reason of their own conduct or acts.
Common
stock
We have a total
of shares
of our common stock outstanding. Additionally, options to
purchase shares
of common stock are currently outstanding and have been granted
to certain members of our management and employees
and shares
have been reserved for future grants. We have reserved 10% of
our outstanding shares of common stock for grant of awards under
the 2007 Plan (which shall be adjusted each year to remain at
10% of the outstanding shares of our common stock), plus all
shares of common stock that remain available for grant of awards
under the prior plan, plus shares of common stock subject to
outstanding awards under the prior plan that later cease to be
subject to those awards for any reason other than those awards
having been exercised. Upon completion of this offering, we will
have shares
of common stock outstanding, or shares if the underwriters
exercise their over-allotment option in full.
Holders of our common or restricted stock are entitled to one
vote for each share held on all matters submitted to a vote of
our stockholders. Because holders of common stock do not have
cumulative voting rights, the holders of a majority of the
shares of common stock can elect all of the members of the board
of directors standing for election.
Holders of our common stock are entitled to receive dividends
if, as and when such dividends are declared by our board of
directors out of assets legally available therefor after payment
of dividends required to be paid on shares of preferred stock,
if any. Upon our dissolution, liquidation or winding up, and
subject to any prior rights of outstanding preferred stock, the
holders of our common stock will be entitled to share pro rata
in the distribution of all our assets available for distribution
to our stockholders after satisfaction of our debts and other
liabilities and the payment of the liquidation preference of any
preferred stock that may be outstanding. There are no redemption
or sinking fund provisions applicable to the common stock. All
outstanding shares of common stock are fully paid and
nonassessable. The holders of our common stock have no
preemptive, conversion, redemption or other subscription rights.
The rights, preferences and privileges of holders of common
stock are subject to, and may be adversely affected by, the
rights of holders of shares of any series of preferred stock
that we may designate and issue in the future.
Preferred
stock
Subject to the provisions of our restated certificate of
incorporation and limitations prescribed by law, our board of
directors is authorized, without further stockholder approval,
to establish and to issue from time to time one or more classes
or series of preferred stock, par value
106
$0.01 per share, covering up to an aggregate of
10,000,000 shares of preferred stock. Each class or series
of preferred stock will cover the number of shares and will have
preferences, voting powers, qualifications and special or
relative rights or privileges as is determined by the board of
directors, which may include, among others, dividend rights,
liquidation preferences, voting rights, conversion rights,
preemptive rights and redemption rights.
The rights of the holders of common stock will be subject to the
rights of holders of any preferred stock issued in the future.
The issuance of preferred stock could adversely affect the
voting power of holders of common stock and reduce the
likelihood that common stockholders will receive dividend
payments and payments upon liquidation. The issuance of
preferred stock could also have the effect of decreasing the
market price of the common stock and could delay, deter or
prevent a change in control of our company.
The existence of authorized but unissued shares of preferred
stock could have anti-takeover effects because we could issue
preferred stock with special dividend or voting rights that
could discourage potential bidders. For example, a business
combination could be impeded by the issuance of a series of
preferred stock containing class voting rights that would enable
the holder or holders of such series to block any such
transaction. Alternatively, a business combination could be
facilitated by the issuance of a series of preferred stock
having sufficient voting rights to provide a required percentage
vote of our stockholders. In addition, under some circumstances,
the issuance of preferred stock could adversely affect the
voting power and other rights of the holders of common stock and
could also affect the likelihood that holders of our common
stock will receive dividend payments and payments on
liquidation. Although prior to issuing any series of preferred
stock our board of directors will be required to make a
determination as to whether the issuance is in the best interest
of our stockholders, our board of directors could act in a
manner that would discourage an acquisition attempt or other
transaction that some, or a majority, of our stockholders might
believe to be in their best interests or in which our
stockholders might receive a premium for their stock over
prevailing market prices of such stock. Our board of directors
does not at present intend to seek stockholder approval prior to
any issuance of currently authorized preferred stock, unless
otherwise required by law or applicable stock exchange
requirements.
Registration
rights agreement
In connection with the contribution transaction and certain
other transactions, we entered into a registration rights
agreement with certain holders of our common stock prior to this
offering. See Certain relationships and related party
transactionsRegistration rights agreement.
Anti-takeover
effects of provisions of Delaware law, our restated certificate
of incorporation and restated bylaws
A number of provisions in our restated certificate of
incorporation, our restated bylaws and the DGCL may make it more
difficult to acquire control of us. These provisions could
deprive our stockholders of opportunities to realize a premium
on the shares of common stock owned by them. In addition, these
provisions may adversely affect the prevailing market price of
our common stock. These provisions are intended to:
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enhance the likelihood of continuity and stability in the
composition of the board of directors and in the policies
formulated by the board of directors;
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107
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discourage transactions which may involve an actual or
threatened change in control of us;
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discourage tactics that may be involved in proxy fights; and
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encourage persons seeking to acquire control of our company to
consult first with the board of directors to negotiate the terms
of any proposed business combination or offer.
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Written consent of stockholders.
Our restated
certificate of incorporation and restated bylaws provide that
any action required or permitted to be taken by our stockholders
must be taken at a duly called meeting of stockholders and not
by written consent.
Call of special stockholder meetings.
Our restated
bylaws provide that stockholders are not permitted to call
special meetings of stockholders. Only our board of directors,
chairman or Chief Executive Officer is permitted to call a
meeting of stockholders.
Amending the bylaws.
Our restated certificate of
incorporation permits our board of directors to adopt, alter or
repeal any provision of the restated bylaws or to make new
bylaws. Our restated certificate of incorporation also provides
that our restated bylaws may be amended by the affirmative vote
of at least 67% of the voting power of the outstanding shares of
our capital stock.
Classified board.
Our restated certificate of
incorporation provides that our board of directors is divided
into three classes of directors, with the classes to be as
nearly equal in number as possible. As a result, approximately
one-third of our board of directors will be elected each year.
The classification of directors has the effect of making it more
difficult for stockholders to change the composition of our
board of directors. Our restated certificate of incorporation
and restated bylaws provide that the number of directors will be
fixed from time to time pursuant to a resolution adopted by the
board of directors.
Advance notice procedures for stockholder proposals and
director nominations.
Our restated bylaws provide that
stockholders seeking to bring business before an annual meeting
of stockholders, or to nominate candidates for election as
directors at an annual meeting of stockholders, must provide
timely notice thereof in writing. To be timely, a
stockholders notice generally must be delivered to or
mailed and received at our principal executive offices not less
than 90 and no more than 120 calendar days before the first
anniversary of the date on which we first mailed our proxy
materials for the preceding years annual meeting of
stockholders. In addition, our restated bylaws specify
requirements for the form and content of a stockholders
notice. These provisions may preclude stockholders from bringing
matters before an annual meeting of stockholders or from making
nominations for directors at an annual meeting of stockholders.
Filling board of directors vacancies; removal.
Our
restated certificate of incorporation provides that vacancies
and newly created directorships resulting from any increase in
the authorized number of directors may be filled by the
affirmative vote of a majority of our directors then in office,
though less than a quorum. Each director will hold office until
his or her successor is elected and qualified, or until the
directors earlier death, resignation, retirement or
removal from office. Any director may resign at any time upon
written notice to us. Our restated certificate of incorporation
provides, in accordance with the DGCL, that the stockholders may
remove directors only for cause and by the affirmative vote of
at least 67% of the voting power of all of the then-outstanding
shares of our common stock. We believe that the removal of
directors by the stockholders only for cause, together with the
classification of the board of
108
directors, will promote continuity and stability in our
management and policies and that this continuity and stability
will facilitate long-range planning.
No cumulative voting.
The DGCL provides that
stockholders are not entitled to use cumulative voting in the
election of directors unless our restated certificate of
incorporation provides otherwise. Under cumulative voting, a
majority stockholder holding a sufficient percentage of a class
of shares may be able to ensure the election of one or more
directors. Our restated certificate of incorporation expressly
precludes cumulative voting.
Authorized but unissued shares.
Our restated
certificate of incorporation provides that the authorized but
unissued shares of preferred stock are available for future
issuance without stockholder approval. These additional shares
may be utilized for a variety of corporate purposes, including
future public offerings to raise additional capital, corporate
acquisitions and employee benefit plans. The existence of
authorized but unissued shares of common stock and preferred
stock could discourage an attempt to obtain control of us by
means of a proxy contest, tender offer, merger or otherwise.
Delaware Business Combination Statute.
We are
subject to Section 203 of the DGCL regulating corporate
takeovers. This section prevents a Delaware corporation from
engaging in a business combination which includes a merger or
sale of more than 10% of the corporations assets with a
stockholder who owns 15% or more of the corporations
outstanding voting stock, as well as affiliates and associates
of any of those persons. That prohibition extends for three
years following the date that stockholder acquired that amount
of stock unless:
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the transaction in which that stockholder acquired the stock is
approved by the board of directors prior to that date;
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upon completion of the transaction that resulted in the
acquisition of the stock, the stockholder owned at least 85% of
the voting stock of the corporation outstanding at the time the
transaction commenced, excluding those shares owned by various
employee benefit plans or persons who are directors and also
officers; or
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on or after the date the stockholder acquired the stock, the
business combination is approved by the board of directors and
authorized at an annual or special meeting of stockholders by
the affirmative vote of at least two-thirds of the outstanding
voting stock that is not owned by the stockholder.
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Stockholders may, by adopting an amendment to our restated
certificate of incorporation or our restated bylaws, elect for
the corporation not to be governed by Section 203 of the
DGCL. Such amendment shall not become effective until
12 months after the date it is adopted or applies to a
stockholder. Neither our restated certificate of incorporation
or restated bylaws exempt us from the restrictions imposed under
Section 203. It is anticipated that the provisions of
Section 203 may encourage companies interested in acquiring
us to negotiate in advance with our board of directors.
Section 203 will not apply to a business combination
between us and Yorktown or a Yorktown affiliate because Yorktown
held more than 15% of our stock prior to the effective date of
our restated certificate of incorporation.
Limitation of liability of directors and officers;
indemnification.
Our restated certificate of
incorporation provides that to the fullest extent permitted by
Delaware law, as that law may be amended and supplemented from
time to time, our directors shall not be personally liable to us
or our stockholders for monetary damages for breach of fiduciary
duty as a director, except for liability (i) for any breach
of the directors duty of loyalty to the company or our
stockholders,
109
(ii) for acts or omissions not in good faith or which
involve intentional misconduct, fraud or a knowing violation of
law, (iii) the payment of dividends in violation of
Section 174 of the DGCL, or (iv) for any transaction
from which the director derived any improper personal benefit.
The effect of the provision of our restated certificate of
incorporation is to eliminate the rights of the company and our
stockholders (through stockholders derivative suits on our
behalf) to recover monetary damages against a director for
breach of the fiduciary duty of care as a director (including
breaches resulting from negligent behavior) except in the
situations described in clauses (i) through
(iv) above. Our restated bylaws also set forth certain
indemnification provisions and provide for the advancement of
expenses incurred by a director in defending a claim by reason
of the fact that he was one of our directors (or was serving as
a director or officer of another entity at our request),
provided that the director agrees to repay the amounts advanced
if the director is not entitled to be indemnified by us under
the provisions of the DGCL. The indemnification provisions of
our restated certificate of incorporation may reduce the
likelihood of derivative litigation against directors and may
discourage or deter stockholders or management from bringing a
lawsuit against directors for breaches of their fiduciary
duties, even though an action, if successful, otherwise might
have benefited us and our stockholders.
The right to indemnification and advancement of expenses are not
exclusive of any other rights to indemnification our directors
or officers may be entitled to under any agreement, vote of
stockholders or disinterested directors or otherwise. We intend
to enter into indemnification agreements with each of our
directors and some of our officers pursuant to which we agree to
indemnify the director or officer against expenses, judgments,
fines or amounts paid in settlement incurred by the director or
officer and arising in his capacity as a director, officer,
employee
and/or
agent
of the company or other enterprise of which he is a director,
officer, employee or agent acting at our request to the maximum
extent permitted by applicable law, subject to certain
limitations. Additionally, under Delaware law, we may purchase
and maintain insurance for the benefit and on behalf of our
directors and officers insuring against all liabilities that may
be incurred by the director or officer in or arising out of his
capacity as our director, officer, employee
and/or
agent.
Transfer agent
and registrar
will be the transfer agent and registrar for our common stock.
Shares eligible
for future sale
Prior to this offering, there has been no public market for our
common stock. Sales of substantial amounts of common stock in
the public market after we complete this offering, or the
perception that such sales may occur, could adversely affect the
prevailing market price of our common stock and could impair our
ability to raise equity capital in the future through the sale
of our equity securities.
As
of ,
2007, we
had shares
of common stock outstanding. Upon the closing of this offering,
we will
have shares
of common stock outstanding and outstanding options to purchase
shares of our common stock. All of the shares of our common
stock sold in this offering will be freely tradable without
restriction or further registration under the Securities Act,
except for any shares purchased by one of our
affiliates as that term is defined in Rule 144
under the Securities Act. All of the shares outstanding other
than the shares sold in
110
this offering (a total
of shares,
or shares
if the underwriters exercise their option to purchase additional
shares in full) will be restricted securities within
the meaning of Rule 144 under the Securities Act and may
not be sold other than through registration under the Securities
Act or pursuant to an exemption from registration, subject to
the restrictions on transfer contained in the
lock-up
agreements described below and in Underwriting.
Persons who may be deemed affiliates generally include
individuals or entities that control, are controlled by or are
under common control with us and may include our officers,
directors and significant stockholders.
Lock-up
arrangements
In connection with this offering, we, our executive officers and
directors and the other holders of our common stock (including
the selling stockholder) have agreed that, during the period
beginning from the date of this prospectus and continuing to and
including the date 180 days after the date of this
prospectus, neither we nor any of them will, directly or
indirectly, offer, sell, offer to sell, contract to sell or
otherwise dispose of any shares of our common stock without the
prior written consent of J.P. Morgan Securities Inc., on
behalf of the underwriters, with limited exceptions. This
lock-up
will
not apply to
approximately shares
that are issuable upon the exercise of options outstanding under
our long-term incentive plan and up to an
additional shares
covered by grants that we are permitted to award under our
existing stock incentive plan during the
180-day
lock-up
period. See Underwriting for a description of these
lock-up
arrangements. Upon the expiration of these
lock-up
agreements, shares,
or shares
if the underwriters exercise their over-allotment option in
full, will be eligible for sale in the public market under
Rule 144 of the Securities Act, subject to volume
limitations and other restrictions contained in Rule 144.
Rule 144
In general, under Rule 144 as currently in effect,
beginning 90 days after the date of this prospectus, a
person, or persons whose shares are aggregated, who have
beneficially owned restricted shares for at least one year,
including the holding period of any prior owner (other than an
affiliate of ours), would be entitled to sell within
any three-month period a number of shares that does not exceed
the greater of (i) 1% of the number of shares of common
stock then outstanding or (ii) the average weekly trading
volume of our common stock on the NASDAQ Global Market during
the four calendar weeks preceding the filing of a Form 144
with respect to the sale.
Sales under Rule 144 are also subject to certain manner of
sale provisions and notice requirements and to the availability
of certain public information about us.
Rule 144(k)
Under Rule 144(k), a person who is not deemed to have been
one of our affiliates at any time during the
90 days preceding a sale, and who has beneficially owned
the shares proposed to be sold for at least two years, including
the holding period of any prior owner (other than an
affiliate or ours) is entitled to sell those shares
without complying with the manner of sale, public information,
volume limitation or notice provisions of Rule 144.
111
Stock issued
under employee plans
We intend to file a registration statement on
Form S-8
under the Securities Act to register
approximately shares
of common stock issuable with respect to options and other
equity incentive awards that have been granted or are reserved
for issuance under our employee plans or otherwise. This
registration statement is expected to be filed following the
effective date of the registration statement of which this
prospectus is a part and will be effective upon filing. Shares
issued under our 2007 Plan will be eligible for resale in the
public market without restriction after the effective date of
the
Form S-8
registration statements, subject to Rule 144 limitations
applicable to affiliates. Under Rule 701 under the
Securities Act, as currently in effect, each of our employees,
officers, directors and consultants who purchased or received
shares pursuant to a written compensatory plan or contract is
eligible to resell these shares 90 days after the effective
date of this offering in reliance upon Rule 144, but
without compliance with specific restrictions. Rule 701
provides that affiliates may sell their
Rule 701 shares under Rule 144 without complying
with the holding period requirement and that non-affiliates may
sell their shares in reliance on Rule 144 without complying
with the holding period, public information, volume limitation
or notice provisions of Rule 144.
Registration
rights
In connection with the contribution transaction and certain
other transactions, we entered into a registration rights
agreement with certain of our stockholders covering shares of
common stock owned by such stockholders. For a description of
the registration rights agreement, see Certain
relationships and related party transactionsRegistration
rights agreement.
112
Material United
States federal income and estate tax considerations for
non-United
States holders
The following is a summary of material United States federal
income and, to a limited extent, estate tax considerations
relating to the purchase, ownership and disposition of our
common stock by persons that are
non-United
States holders (as defined below), but does not purport to be a
complete analysis of all the potential tax considerations
relating thereto. This summary is based upon the current
provisions of the Internal Revenue Code of 1986, as amended, or
the Code, Treasury Regulations, administrative rulings,
published positions of the Internal Revenue Service, or the IRS,
court decisions thereunder and other applicable authorities, all
as now in effect and all of which are subject to change or
differing interpretations, in each case, possibly with
retroactive effect. This summary deals only with
non-United
States holders that will hold our common stock as a
capital asset (generally, property held for
investment). In addition, this discussion does not address all
of the United States federal income tax consequences that may be
relevant to a particular person in light of its particular
circumstances and tax considerations applicable to investors
that may be subject to special rules under United States federal
income tax law, such as (without limitation):
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certain former citizens or residents of the United States;
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stockholders that hold out common stock as part of a straddle,
appreciated financial position, synthetic security, hedge,
conversion transaction or other integrated investment or risk
reduction transaction;
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stockholders who acquired our common stock through the exercise
of employee stock options or otherwise as compensation or
through a tax qualified retirement plan;
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stockholders that are S corporations, entities or
arrangements treated as partnerships for United States federal
income tax purposes or other pass through entities or owners
thereof;
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financial institutions;
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insurance companies;
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tax-exempt entities;
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dealers in securities or foreign currencies; and
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traders in securities that mark to market.
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Furthermore, this summary does not address any aspect of state,
local, foreign or other tax laws or the gift tax or alternative
minimum tax provisions of the Code.
If a partnership (including an entity or arrangement treated as
a partnership for United States federal income tax purposes)
holds the common stock, the tax treatment of a partner will
generally depend upon the status of the partner and the
activities of the partnership. If you are a partnership
(including an entity or arrangement treated as a partnership for
United States federal income tax purposes) holding our common
stock or a partner of such a partnership, you should consult
your tax advisor.
We have not sought any ruling from the IRS with respect to the
statements made and the conclusions reached in the following
summary. No assurance can be given that the IRS would not
assert, or that a court would not sustain, a position contrary
to any of those set forth below.
113
As used in this discussion, except as otherwise defined for
estate tax purposes, a
non-United
States holder is a beneficial owner of common stock (other
than an entity treated as a partnership for United States
federal income tax purposes) that for United States federal
income tax purposes is not:
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an individual who is a citizen or resident of the United States,
including an alien individual who is a lawful permanent resident
of the United States or who meets the substantial
presence test under Section 7701(b) of the Code;
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a corporation, or other entity treated as a corporation for
United States federal income tax purposes, that was created or
organized in or under the laws of the United States or any
political subdivision thereof;
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an estate whose income is subject to United States federal
income taxation regardless of its source; or
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a trust (i) if its administration is subject to the
supervision of a court within the United States and one or more
United States persons have the authority to control all
substantial decisions of the trust or (ii) that has a valid
election in effect under applicable United States Treasury
Regulations to be treated as a United States person.
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INVESTORS CONSIDERING THE PURCHASE OF COMMON STOCK SHOULD
CONSULT THEIR OWN TAX ADVISORS WITH RESPECT TO THE APPLICATION
OF THE UNITED STATES FEDERAL INCOME AND ESTATE TAX LAWS TO THEIR
PARTICULAR SITUATIONS AS WELL AS ANY TAX CONSEQUENCES ARISING
UNDER THE LAWS OF ANY STATE, LOCAL OR FOREIGN TAXING
JURISDICTION OR UNDER ANY APPLICABLE TAX TREATY.
Dividends
We do not presently expect to declare or pay any dividends on
our common stock in the foreseeable future. However, if we do
make distributions on our common stock, such distributions will
constitute dividends for United States federal income tax
purposes to the extent paid from our current or accumulated
earnings and profits, as determined under United States federal
income tax principles. Distributions in excess of earnings and
profits will constitute a return of capital that is applied
against and reduces the
non-United
States holders adjusted tax basis in our common stock (on
a share by share basis). Any remaining excess will be treated as
gain realized on the sale or other disposition of the common
stock and will be treated as described under Gain on
disposition of common stock below. The gross amount of any
dividend (out of earnings and profits) paid to a
non-United
States holder of common stock generally will be subject to
United States withholding tax at a rate of 30% unless the holder
is entitled to an exemption from or reduced rate of withholding
under an applicable income tax treaty. In order to receive a
reduced treaty rate, prior to the payment of a dividend a
non-United
States holder must provide us with a properly completed IRS
Form W-8BEN
(or successor form) certifying qualification for the reduced
rate.
Dividends paid to a
non-United
States holder that are effectively connected with a trade or
business conducted by the
non-United
States holder in the United States (and, where a tax treaty
applies, are attributable to a permanent establishment
maintained by the
non-United
States holder in the United States) generally will be exempt
from the withholding tax described above and instead will be
subject to United States federal income tax on a net income
basis at the regular graduated individual or corporate United
States federal income tax rates in much
114
the same manner as if the
non-United
States holder were a resident of the United States. In order to
obtain this exemption from withholding tax prior to the payment
of a dividend, a
non-United
States holder must provide us with an IRS
Form W-8ECI
or
W-8BEN,
as applicable, (or other applicable form) properly certifying
eligibility for such exemption. A corporate
non-United
States holder also may be subject to an additional branch
profits tax at a rate of 30% of its effectively connected
earnings and profits or such lower rate as may be specified by
an applicable tax treaty.
A
non-United
States holder who provides us with an IRS
Form W-8BEN
or an IRS
Form W-8ECI
may be required to periodically update such form.
If a
non-United
States holder is eligible for a reduced rate of United States
withholding tax pursuant to an income tax treaty, the
non-United
States holder may obtain a refund of any excess amounts withheld
by filing an appropriate claim for refund with the IRS.
Gain on
disposition of common stock
Any gain realized on the sale or other disposition of our common
stock by a
non-United
States holder generally will not be subject to United States
federal income tax unless:
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the gain is effectively connected with a trade or business
conducted by the
non-United
States holder in the United States, and, if required by an
applicable income tax treaty, is attributable to a United States
permanent establishment of the
non-United
States holder;
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the
non-United
States holder is an individual who is present in the United
States for 183 days or more in the taxable year of
disposition and certain other conditions are met; or
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we are or have been a United States real property holding
corporation for United States federal income tax purposes.
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A
non-corporate
non-United
States holder described in the first bullet point immediately
above will be subject to tax on the net gain derived from the
sale under regular graduated United States federal income tax
rates. If a
non-United
States holder that is a foreign corporation falls under the
first bullet point immediately above, it generally will be
subject to tax on its net gain in the same manner as if it were
a United States person as defined under the Code and, in
addition, may be subject to the branch profits tax equal to 30%
of its effectively connected earnings and profits or at such
lower rate as may be specified by an applicable income tax
treaty.
An individual described in the second bullet point will be
subject to tax on such gain (net of certain U.S. source
losses) at a rate of 30%, unless otherwise specified by an
applicable treaty.
As to the third bullet point, we believe that we are currently a
United States real property holding corporation for
United States federal income tax purposes. So long as our common
stock is regularly traded on an established securities
market, only a
non-United
States holder who holds or held (at any time during the shorter
of the five year period preceding the date of disposition or the
holders holding period) more than 5% of our common stock
will be subject to United States federal income tax on the
disposition of our common stock. If our common stock were not
considered to be regularly traded on an established
securities market, all
non-United
States holders would be subject to United States federal income
tax on a disposition of our common stock.
115
Non-United
States holders should consult their own tax advisors with
respect to the application of the foregoing rules to their
ownership and disposition of our common stock.
Federal estate
taxes
If an individual
non-United
States holder (which for United States federal estate tax
purposes is neither a citizen nor a domiciliary of the United
States) is treated as the owner, or has made certain lifetime
transfers, of an interest in our common stock, then the value
thereof will be included in his or her gross estate for United
States federal estate tax purposes, and such individuals
estate and may be subject to United States federal estate tax,
unless an applicable estate tax treaty provides otherwise.
Information
reporting and backup withholding
We must report annually to the IRS and to each
non-United
States holder the amount of dividends paid to such holder and
the tax withheld with respect to such dividends, regardless of
whether withholding was required. Copies of the information
returns reporting such dividends and withholding may also be
made available to the tax authorities in the country in which
the
non-United
States holder resides under the provisions of an applicable
income tax treaty or other agreement.
Payments of dividends or of proceeds on the disposition of stock
made to a
non-United
States holder may be subject to additional information reporting
and backup withholding. Backup withholding will not apply if the
non-United
States holder establishes an exemption, for example, by properly
certifying its
non-United
States status on an IRS
Form W-8BEN
(or successor form).
Backup withholding is not an additional tax. Any amounts
withheld under the backup withholding rules may be allowed as a
refund or a credit against a
non-United
States holders United States federal income tax liability
provided the required information is timely furnished to the IRS.
116
Underwriting
J.P. Morgan Securities Inc. is acting as sole book-runner and
joint lead manager, and A.G. Edwards & Sons, Inc. is
acting as joint lead manager for this offering.
We, the selling stockholder and the underwriters named below
have entered into an underwriting agreement covering the common
stock to be sold in this offering. Each underwriter has
severally agreed to purchase, and we and the selling stockholder
have agreed to sell to each underwriter, the number of shares of
common stock set forth opposite their names in the following
table.
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Name
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Number
of shares
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J.P. Morgan Securities Inc.
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A.G. Edwards & Sons,
Inc.
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Total
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The underwriting agreement provides that if the underwriters
take any of the shares presented in the table above, then they
must take all of the shares. No underwriter is obligated to take
any shares allocated to a defaulting underwriter except under
limited circumstances. The underwriting agreement provides that
the obligations of the underwriters are subject to certain
conditions precedent, including the absence of any material
adverse change in our business and the receipt of certain
certificates, opinions and letters from us, our counsel and our
independent auditors.
The underwriters are offering the shares of common stock,
subject to the prior sale of shares, and when, as and if such
shares are delivered to and accepted by them. The underwriters
will initially offer to sell shares to the public at the initial
public offering price shown on the front cover page of this
prospectus. The underwriters may sell shares to securities
dealers at a discount of up to $
per share from the initial public offering price. Any such
securities dealers may resell shares to certain other brokers or
dealers at a discount of up to $
per share from the initial public offering price. After the
initial public offering, the underwriters may vary the public
offering price and other selling terms.
If the underwriters sell more shares than the total number shown
in the table above, the underwriters have the option to buy up
to an
additional shares
of common stock from us and the selling stockholder to cover
such sales. They may exercise this option during the
30-day
period from the date of this prospectus. If any shares are
purchased under this option, the underwriters will purchase
shares in approximately the same proportion as shown in the
table above. If any additional shares of common stock are
purchased, the underwriters will offer the additional shares on
the same terms as those on which the shares are being offered.
At our request, the underwriters have reserved up
to shares
of common stock offered hereby for sale to our employees and
other persons associated with us or our officers or directors,
which we refer to as our directed share program. The number of
shares of common stock available for sale to the general public
in the initial public offering will be reduced to the extent
these persons purchase any reserved shares pursuant to the
directed share program. Any shares not so purchased will be
offered by the underwriters to the general public on the same
basis as the other shares offered in this prospectus.
117
The following table shows the per share and total underwriting
discounts that we and the selling stockholder will pay to the
underwriters. These amounts are shown assuming both no exercise
and full exercise of the underwriters option to purchase
additional shares.
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Paid by
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Paid by
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Approach
Resources Inc.
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selling
stockholder
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Without
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With full
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Without
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With full
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over-allotment
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over-allotment
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over-allotment
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over-allotment
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exercise
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exercise
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exercise
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exercise
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Per share
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$
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$
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$
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$
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Total
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$
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$
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$
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$
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The underwriters have advised us that they may make short sales
of our common stock in connection with this offering, resulting
in the sale by the underwriters of a greater number of shares
than they are required to purchase pursuant to the underwriting
agreement. The short position resulting from those short sales
will be deemed a covered short position to the
extent that it does not exceed the shares subject to the
underwriters over-allotment option and will be deemed a
naked short position to the extent that it exceeds
that number. A naked short position is more likely to be created
if the underwriters are concerned that there may be downward
pressure on the trading price of the common stock in the open
market that could adversely affect investors who purchase shares
in this offering. The underwriters may reduce or close out their
covered short position either by exercising the over-allotment
option or by purchasing shares in the open market. In
determining which of these alternatives to pursue, the
underwriters will consider the price at which shares are
available for purchase in the open market as compared to the
price at which they may purchase shares through the
over-allotment option. Any naked short position will
be closed out by purchasing shares in the open market. Similar
to the other stabilizing transactions described below, open
market purchases made by the underwriters to cover all or a
portion of their short position may have the effect of
preventing or retarding a decline in the market price of our
common stock following this offering. As a result, our common
stock may trade at a price that is higher than the price that
otherwise might prevail in the open market.
The underwriters have advised us that, pursuant to
Regulation M under the Securities Exchange Act of 1934,
they may engage in transactions, including stabilizing bids or
the imposition of penalty bids, that may have the effect of
stabilizing or maintaining the market price of the shares of
common stock at a level above that which might otherwise prevail
in the open market. A stabilizing bid is a bid for
or the purchase of shares of common stock on behalf of the
underwriters for the purpose of fixing or maintaining the price
of the common stock. A penalty bid is an arrangement
permitting the underwriters to claim the selling concession
otherwise accruing to an underwriter or syndicate member in
connection with the offering if the common stock originally sold
by that underwriter or syndicate member is purchased by the
underwriters in the open market pursuant to a stabilizing bid or
to cover all or part of a syndicate short position. The
underwriters have advised us that stabilizing bids and open
market purchases may be effected on the NASDAQ Global Market, in
the over-the-counter market or otherwise and, if commenced, may
be discontinued at any time.
One or more of the underwriters may facilitate the marketing of
this offering online directly or through one of its affiliates.
In those cases, prospective investors may view offering terms
and a
118
prospectus online and, depending upon the particular
underwriter, place orders online or through their financial
advisor.
We estimate that our total expenses for this offering, excluding
underwriting discounts, will be approximately
$ .
We and the selling stockholder have agreed to indemnify the
underwriters against certain liabilities, including liabilities
under the Securities Act.
We, our executive officers and directors, the selling
stockholder and certain significant holders of our outstanding
common stock have agreed that, during the period beginning from
the date of this prospectus and continuing to and including the
date 180 days after the date of this prospectus, neither we
nor any of them will, directly or indirectly, offer, sell, offer
to sell, contract to sell or otherwise dispose of any shares of
our common stock without the prior written consent of
J.P. Morgan Securities Inc., except in limited
circumstances.
The underwriters have informed us that they do not intend sales
to discretionary accounts to exceed 5% of the total number of
shares of our common stock offered by them and that no sales to
discretionary accounts may be made without prior written
approval of the customer.
We have applied to list our common stock on the NASDAQ Global
Market under the symbol AREX. The underwriters
intend to sell shares of our common stock so as to meet the
distribution requirements of this listing.
There has been no public market for the common stock prior to
this offering. We, the selling stockholder and the underwriters
will negotiate the initial public offering price. In determining
the initial public offering price, we, the selling stockholder
and the underwriters expect to consider a number of factors in
addition to prevailing market conditions, including:
|
|
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the information set forth in this prospectus and otherwise
available to the underwriters;
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the history of and prospects for our industry;
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an assessment of our management;
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our present operations;
|
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our historical results of operations;
|
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the trend of our revenues and earnings;
|
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our earnings prospects;
|
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the general condition of the securities markets at the time of
this offering;
|
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|
the recent market prices of, and demand for, publicly traded
common stock of generally comparable companies; and
|
|
|
other factors deemed relevant by us, the selling stockholder and
the underwriters.
|
We, the selling stockholder and the underwriters will consider
these and other relevant factors in relation to the price of
similar securities of generally comparable companies. Neither
the Company, the selling stockholder nor the underwriters can
assure investors that an active trading market will develop for
the common stock, or that the common stock will trade in the
public market at or above the initial public offering price.
119
Affiliates of J.P. Morgan Securities Inc. will receive in
excess of 10% of the net proceeds from this offering. According
to Rule 2720 of the National Association of Securities
Dealers, Inc.s, also referred to as the NASD, Conduct
Rules, the offering must comply with the requirements of
Rule 2720 of the NASD Conduct Rules. That rule requires
that the initial public offering price can be no higher than
that recommended by a qualified independent
underwriter, as defined by the NASD. In view of
J.P. Morgan Securities Inc.s relationship with us,
the offering is being conducted in accordance with the rules of
the NASD, and A.G. Edwards & Sons, Inc. will serve in
the capacity of qualified independent underwriter
and will perform due diligence investigations and review and
participate in the preparation of the registration statement of
which this prospectus forms a part. We have agreed to reimburse
A.G. Edwards & Sons, Inc. for its expenses, if any,
incurred as a result of its engagement as qualified independent
underwriter. The underwriters may not confirm sales to any
discretionary account without the prior specific written
approval of the customer.
From time to time in the ordinary course of their respective
businesses, certain of the underwriters and their affiliates
perform various financial advisory, investment banking and
commercial banking services from time to time for us and our
affiliates. For example, certain affiliates of the underwriters
to this offering are lenders under our revolving credit
facility. JPMorgan Chase Bank, N.A., an affiliate of
J.P. Morgan Securities Inc., is a lender under our
revolving credit facility. See Use of proceeds.
Legal
matters
The validity of our shares of common stock offered by this
prospectus will be passed upon for us by Thompson &
Knight LLP, Dallas, Texas. Legal matters in connection with this
offering will be passed upon for the underwriters by Cahill
Gordon & Reindel
LLP
, New York, New York.
Experts
The combined financial statements of Approach Resources Inc. and
affiliated entities as of December 31, 2005 and 2006, and
for each of the three years in the period ended
December 31, 2006 included in this prospectus have been
audited by Hein & Associates LLP, independent
registered public accountants, as stated in their report
appearing in this registration statement, and have been so
included in reliance upon the report of such firm given upon
their authority as experts in accounting and auditing.
The Historical Summaries of Revenues and Direct Operating
Expenses of Properties to be Acquired by Approach Resources Inc.
as of December 31, 2005 and 2006, and for the years then
ended included in this prospectus have been audited by
Hein & Associates LLP, independent registered public
accountants, as stated in their report appearing in this
registration statement, and have been so included in reliance
upon the report of such firm given upon their authority as
experts in accounting and auditing
The information included in this prospectus regarding estimated
quantities of proved reserves, the future net revenues from
those reserves and their present value is based, in part, on our
estimates of the proved reserves, present values of proved
reserves as of December 31, 2006 prepared by
DeGolyer & MacNaughton, an independent engineering
firm, and present values of proved reserves as of
December 31, 2005 and 2004 prepared by Cawley,
Gillespie & Associates,
120
Inc, an independent engineering firm. These estimates are
included in this prospectus in reliance upon the authority of
DeGolyer & MacNaughton and Cawley, Gillespie and
Associates, Inc. as experts in these matters.
Where you can
find more information
We have filed with the SEC a registration statement on
Form S-1,
including exhibits, under the Securities Act with respect to the
common stock to be sold in this offering. This prospectus, which
constitutes a part of the registration statement, does not
contain all of the information set forth in the registration
statement or the exhibits that are part of the registration
statement. For further information about us and our common
stock, you should refer to the registration statement. Any
statements made in this prospectus as to the contents of any
contract, agreement or other document are not necessarily
complete. With respect to each such contract, agreement or other
document filed as an exhibit to the registration statement, you
should refer to the exhibit for a more complete description of
the matter involved, and each statement in this prospectus shall
be deemed qualified in its entirety by this reference.
You may read, without charge, and copy, at prescribed rates, all
or any portion of the registration statement or any reports,
statements or other information in the files at the public
reference facilities of the SECs principal office at
Room 1580, 100 F Street, N.E.,
Washington, D.C., 20549. You can request copies of these
documents upon payment of a duplicating fee by writing to the
SEC. You may call the SEC at
1-800-SEC-0330
for further information on the operation of its public reference
rooms. Our filings, including the registration statement, will
also be available to you on the Internet web site maintained by
the SEC at
http://www.sec.gov.
After the completion of this offering, we will file with or
furnish to the SEC periodic reports and other information. These
reports and other information may be inspected and copied at the
public reference facilities maintained by the SEC or obtained
from the SECs website as provided above. After the
completion of this offering, we expect our website on the
Internet to be located at
http://www.approachresources.com
,
and we expect to make our periodic reports and other information
filed with or furnished to the SEC available, free of charge,
through our website, as soon as reasonably practical after those
reports and other information are electronically filed with or
furnished to the SEC. Information on our website or any other
website is not incorporated by reference into this prospectus
and does not constitute a part of this prospectus. You may also
request a copy of these filings at no cost, by writing or
telephoning us at: Approach Resources Inc., 6300 Ridglea Place,
Suite 1100, Fort Worth, Texas 76116,
(817) 989-9000.
121
Glossary of
selected oil and gas terms
The following is a description of the meanings of some of the
oil and gas industry terms used in this prospectus.
3-D
seismic.
(Three Dimensional Seismic Data) Geophysical
data that depicts the subsurface strata in three dimensions.
3-D
seismic
data typically provides a more detailed and accurate
interpretation of the subsurface strata than two dimensional
seismic data.
Basin.
A large natural depression on the
earths surface in which sediments generally brought by
water accumulate.
Bbl.
One stock tank barrel, of 42 U.S. gallons
liquid volume, used herein in reference to oil, condensate or
natural gas liquids.
Bcfe.
Billion cubic feet of natural gas equivalent,
determined using the ratio of six Mcf of gas to one Bbl of oil,
condensate or gas liquids.
Biogenic gas.
Natural gas formed at low temperatures
by anaerobic bacterial decomposition of organic matter.
Btu or British Thermal Unit.
The quantity of heat
required to raise the temperature of one pound of water by one
degree Fahrenheit.
Completion.
The installation of permanent equipment
for the production of oil or gas.
Conventional resources or reserves.
Natural gas or
oil resources or reserves that are generally trapped by
hydrodynamic processes and commonly contain discrete, measurable
accumulations of hydrocarbons.
Developed acreage.
The number of acres that are
allocated or assignable to productive wells or wells that are
capable of production.
Developmental well.
A well drilled within the proved
boundaries of an oil or gas reservoir with the intention of
completing the stratigraphic horizon known to be productive.
Dry hole.
A well found to be incapable of producing
hydrocarbons in sufficient quantities such that proceeds from
the sale of such production exceed production expenses and taxes.
Dry hole costs.
Costs incurred in drilling a well,
assuming a well is not successful, including plugging and
abandonment costs.
Exploitation.
Ordinarily considered to be a form of
development within a known reservoir.
Exploratory well.
A well drilled to find and produce
oil or gas reserves not classified as proved, to find a new
reservoir in a field previously found to be productive of oil or
gas in another reservoir or to extend a known reservoir.
Farmout.
An agreement whereby the owner of a
leasehold or working interest agrees to assign an interest in
certain specific acreage to the assignees, retaining an interest
such as an overriding royalty interest, an oil and gas payment,
offset acreage or other type of interest, subject to the
drilling of one or more specific wells or other performance as a
condition of the assignment.
122
Field.
An area consisting of either a single
reservoir or multiple reservoirs, all grouped on or related to
the same individual geological structural feature
and/or
stratigraphic condition.
Finding and development costs.
Capital costs
incurred in the acquisition, exploration, development,
exploitation and revisions of proved oil and gas reserves
divided by proved reserve additions.
Fracing or Fracture stimulation technology.
The
technique of improving a wells production or injection
rates by pumping a mixture of fluids into the formation and
rupturing the rock, creating an artificial channel. As part of
this technique, sand or other material may also be injected into
the formation to keep the channel open, so that fluids or gases
may more easily flow through the formation.
Gross acres or gross wells.
The total acres or
wells, as the case may be, in which a working interest is owned.
Lease operating expenses.
The expenses of lifting
oil or gas from a producing formation to the surface, and the
transportation and marketing thereof, constituting part of the
current operating expenses of a working interest, and also
including labor, superintendence, supplies, repairs, short lived
assets, maintenance, allocated overhead costs, ad valorem taxes
and other expenses incidental to production, but excluding lease
acquisition or drilling or completion expenses.
MBbls.
Thousand barrels of oil or other liquid
hydrocarbons.
Mcf.
Thousand cubic feet of natural gas.
Mcfe.
Thousand cubic feet equivalent, determined
using the ratio of six Mcf of gas to one Bbl of oil, condensate
or gas liquids.
MMBbls.
Million barrels of oil or other liquid
hydrocarbons.
MMBoe.
Million barrels of oil equivalent, with six
thousand cubic feet of natural gas being equivalent to one
barrel of oil.
MMBtu.
Million British thermal units.
MMcf.
Million cubic feet of gas.
MMcfe.
Million cubic feet equivalent, determined
using the ratio of six Mcf of gas to one Bbl of oil, condensate
or gas liquids.
Net acres or net wells.
The sum of the fractional
working interests owned in gross acres or wells, as the case may
be.
NYMEX.
New York Mercantile Exchange.
Productive well.
A well that is found to be capable
of producing hydrocarbons in sufficient quantities such that
proceeds from the sale of such production exceed production
expenses and taxes.
Prospect.
A specific geographic area which, based on
supporting geological, geophysical or other data and also
preliminary economic analysis using reasonably anticipated
prices and costs, is deemed to have potential for the discovery
of commercial hydrocarbons.
123
Proved developed producing reserves.
Proved
developed reserves that are expected to be recovered from
completion intervals currently open in existing wells and
capable of production to market.
Proved developed reserves.
Proved reserves that can
be expected to be recovered from existing wells with existing
equipment and operating methods.
Proved reserves.
The estimated quantities of oil,
gas and gas liquids that geological and engineering data
demonstrate with reasonable certainty to be recoverable in
future years from known reservoirs under existing economic and
operating conditions.
Proved undeveloped reserves or PUDs.
Proved
reserves that are expected to be recovered from new wells on
undrilled acreage or from existing wells where a relatively
major expenditure is required for recompletion.
PV-10
or
present value of estimated future net revenues.
An
estimate of the present value of the estimated future net
revenues from proved oil and gas reserves at a date indicated
after deducting estimated production and ad valorem taxes,
future capital costs and operating expenses, but before
deducting any estimates of federal income taxes. The estimated
future net revenues are discounted at an annual rate of 10%, in
accordance with the Securities and Exchange Commissions
practice, to determine their present value. The
present value is shown to indicate the effect of time on the
value of the revenue stream and should not be construed as being
the fair market value of the properties. Estimates of future net
revenues are made using oil and gas prices and operating costs
at the date indicated and held constant for the life of the
reserves.
Recompletion.
The addition of production from
another interval or formation in an existing wellbore.
Reserve life index.
This index is calculated by
dividing year-end reserves by our annualized December 2006
average net daily production to estimate the number of years of
remaining production.
Reservoir.
A porous and permeable underground
formation containing a natural accumulation of producible oil
and/or
gas
that is confined by impermeable rock or water barriers and is
individual and separate from other reservoirs.
Spacing.
The distance between wells producing from
the same reservoir. Spacing is expressed in terms of acres,
e.g.,
40-acre
spacing, and is established by regulatory agencies.
Standardized Measure.
The present value of estimated
future net revenues to be generated from the production of
proved reserves, determined in accordance with the rules and
regulations of the SEC (using prices and costs in effect as of
the period end date) without giving effect to non-property
related expenses such as general and administrative expenses,
debt service and future income tax expenses or to depreciation,
depletion and amortization and discounted using an annual
discount rate of 10%. Standardized measure does not give effect
to derivative transactions.
Tcfe.
Trillion cubic feet equivalent, determined
using the ratio of six Mcf of gas to one Bbl of oil, condensate
or gas liquids.
124
Thermogenic gas.
Natural gas formed by thermal
cracking of sedimentary organic matter into hydrocarbon liquids
and gas, and thermal cracking of oil at high temperatures into
gas and pyrobitumen.
Tight gas sands.
A formation with low permeability
that produces natural gas with low flow rates for long periods
of time.
Unconventional resources or reserves.
Natural gas or
oil resources or reserves from (i) low-permeability sandstone
and shale formations, such as tight gas and gas shales,
respectively, and (ii) coalbed methane.
Undeveloped acreage.
Lease acreage on which wells
have not been drilled or completed to a point that would permit
the production of commercial quantities of oil or gas regardless
of whether or not such acreage contains proved reserves.
Wellbore.
The hole drilled by the bit that is
equipped for gas and oil production on a completed well. Also
called well or borehole.
Working interest.
The operating interest that gives
the owner the right to drill, produce and conduct operating
activities on the property and receive a share of production.
Workover.
Operations on a producing well to restore
or increase production.
/d.
Per day when used with volumetric
units or dollars.
125
Index to
financial statements of Approach Resources Inc. and affiliated
entities
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Page
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Approach Resources Inc. and
Affiliated Entities Combined Financial Statements:
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Annual Financial
Statements
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F-2
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F-3
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F-4
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F-5
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F-6
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F-7
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Unaudited Financial
Statements
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F-24
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F-25
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F-26
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F-27
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F-28
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Historical Summaries of
Revenues and Direct Operating Expenses of Properties to be
Acquired by Approach Resources Inc.
|
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F-32
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F-33
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F-34
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F-1
Report of
independent registered public accounting firm
To the Board of Directors
Approach Resources Inc.
Fort Worth, Texas
We have audited the accompanying combined balance sheets of
Approach Resources Inc. and affiliated entities (the
Company) as of December 31, 2005 and 2006, and
the related combined statements of operations, changes in
stockholders equity, and cash flows for each of the three
years in the period ended December 31, 2006. These combined
financial statements are the responsibility of the
Companys management. Our responsibility is to express an
opinion on these financial statements based on our audits.
We conducted our audits in accordance with the standards of the
Public Company Accounting Oversight Board (United States). Those
standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are
free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in
the financial statements. An audit also includes assessing the
accounting principles used and significant estimates made by
management, as well as evaluating the overall financial
statement presentation. We believe that our audits provide a
reasonable basis for our opinion.
In our opinion, the combined financial statements referred to
above present fairly, in all material respects, the financial
position of Approach Resources Inc. and affiliated entities as
of December 31, 2005 and 2006, and the results of their
operations and their cash flows for each of the three years in
the period ended December 31, 2006, in conformity with
U.S. generally accepted accounting principles.
Hein & Associates LLP
Dallas, Texas
May 7, 2007
F-2
|
|
|
|
|
|
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December 31,
|
|
|
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2005
|
|
|
2006
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ASSETS
|
CURRENT ASSETS:
|
|
|
|
|
|
|
|
|
Cash
|
|
$
|
3,219,463
|
|
|
$
|
4,911,241
|
|
Accounts receivable:
|
|
|
|
|
|
|
|
|
Joint interest owners
|
|
|
8,826,035
|
|
|
|
4,812,439
|
|
Oil and gas sales
|
|
|
6,833,717
|
|
|
|
3,457,948
|
|
Unrealized gain on commodity
derivatives
|
|
|
|
|
|
|
4,504,996
|
|
Prepaid expenses and other current
assets
|
|
|
644,740
|
|
|
|
424,081
|
|
|
|
|
|
|
|
Total current assets
|
|
|
19,523,955
|
|
|
|
18,110,705
|
|
PROPERTIES AND
EQUIPMENT:
|
|
|
|
|
|
|
|
|
Oil and gas properties, at cost,
using the successful efforts method of accounting
|
|
|
97,810,212
|
|
|
|
155,627,580
|
|
Furniture, fixtures and equipment
|
|
|
232,648
|
|
|
|
255,451
|
|
|
|
|
|
|
|
|
|
|
98,042,860
|
|
|
|
155,883,031
|
|
Less accumulated depreciation,
depletion and amortization
|
|
|
(9,239,953
|
)
|
|
|
(23,771,187
|
)
|
|
|
|
|
|
|
Net properties and equipment
|
|
|
88,802,907
|
|
|
|
132,111,844
|
|
OTHER ASSETS
|
|
|
88,995
|
|
|
|
86,169
|
|
|
|
|
|
|
|
Total assets
|
|
$
|
108,415,857
|
|
|
$
|
150,308,718
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS
EQUITY
|
CURRENT LIABILITIES:
|
Accounts payable
|
|
$
|
20,529,911
|
|
|
$
|
7,513,219
|
|
Oil and gas payables
|
|
|
6,644,579
|
|
|
|
4,940,415
|
|
Accrued liabilities
|
|
|
1,408,196
|
|
|
|
2,967,780
|
|
Unrealized loss on commodity
derivatives
|
|
|
4,163,098
|
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
32,745,784
|
|
|
|
15,421,414
|
|
NON-CURRENT
LIABILITIES:
|
|
|
|
|
|
|
|
|
Long-term debt
|
|
|
29,425,000
|
|
|
|
47,619,000
|
|
Deferred income taxes
|
|
|
6,447,916
|
|
|
|
17,549,107
|
|
Asset retirement obligations
|
|
|
107,230
|
|
|
|
147,644
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
68,725,930
|
|
|
|
80,737,165
|
|
COMMITMENTS AND CONTINGENCIES
(Notes 8 and 9)
|
|
|
|
|
|
|
|
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STOCKHOLDERS EQUITY
(Note 4)
:
|
|
|
|
|
|
|
|
|
Preferred stock
|
|
|
|
|
|
|
|
|
Common stock
|
|
|
30,000
|
|
|
|
30,654
|
|
Additional paid-in capital
|
|
|
34,501,930
|
|
|
|
43,067,000
|
|
Retained earnings
|
|
|
9,456,318
|
|
|
|
30,658,223
|
|
Loans to stockholders
|
|
|
(4,298,321
|
)
|
|
|
(4,184,324
|
)
|
|
|
|
|
|
|
Total stockholders equity
|
|
|
39,689,927
|
|
|
|
69,571,553
|
|
|
|
|
|
|
|
Total liabilities and
stockholders equity
|
|
$
|
108,415,857
|
|
|
$
|
150,308,718
|
|
|
|
See accompanying notes to these
combined financial statements.
F-3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the years
ended December 31,
|
|
|
|
2004
|
|
|
2005
|
|
|
2006
|
|
|
|
|
REVENUES:
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil and gas sales
|
|
$
|
5,682,280
|
|
|
$
|
40,339,438
|
|
|
$
|
52,893,853
|
|
Overhead and services income
|
|
|
130,309
|
|
|
|
408,016
|
|
|
|
514,209
|
|
|
|
|
|
|
|
Total revenues
|
|
|
5,812,589
|
|
|
|
40,747,454
|
|
|
|
53,408,062
|
|
EXPENSES:
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease operating expense
|
|
|
179,298
|
|
|
|
2,909,639
|
|
|
|
3,888,854
|
|
Severance and production taxes
|
|
|
406,364
|
|
|
|
1,975,105
|
|
|
|
1,735,839
|
|
Exploration
|
|
|
2,396,370
|
|
|
|
733,548
|
|
|
|
1,640,340
|
|
Impairment of non-producing
properties
|
|
|
|
|
|
|
|
|
|
|
558,446
|
|
General and administrative
|
|
|
2,073,675
|
|
|
|
3,066,807
|
|
|
|
2,929,755
|
|
Accretion of discount on asset
retirement obligations
|
|
|
582
|
|
|
|
4,974
|
|
|
|
10,299
|
|
Depletion, depreciation and
amortization
|
|
|
1,223,340
|
|
|
|
8,006,054
|
|
|
|
14,540,570
|
|
|
|
|
|
|
|
Total expenses
|
|
|
6,279,629
|
|
|
|
16,696,127
|
|
|
|
25,304,103
|
|
|
|
|
|
|
|
OPERATING INCOME
(LOSS)
|
|
|
(467,040
|
)
|
|
|
24,051,327
|
|
|
|
28,103,959
|
|
OTHER:
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income (expense), net
|
|
|
200,870
|
|
|
|
(802,065
|
)
|
|
|
(3,813,589
|
)
|
Change in fair value of commodity
derivatives
|
|
|
|
|
|
|
(4,163,098
|
)
|
|
|
8,668,094
|
|
|
|
|
|
|
|
INCOME (LOSS) BEFORE PROVISION
FOR INCOME TAXES
|
|
|
(266,170
|
)
|
|
|
19,086,164
|
|
|
|
32,958,464
|
|
PROVISION FOR INCOME
TAXES
|
|
|
|
|
|
|
7,027,916
|
|
|
|
11,756,559
|
|
|
|
|
|
|
|
NET INCOME (LOSS)
|
|
$
|
(266,170
|
)
|
|
$
|
12,058,248
|
|
|
$
|
21,201,905
|
|
|
|
|
|
|
|
EARNINGS (LOSS) PER
SHARE:
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
(0.14
|
)
|
|
$
|
4.03
|
|
|
$
|
7.04
|
|
|
|
|
|
|
|
Diluted
|
|
$
|
(0.14
|
)
|
|
$
|
4.03
|
|
|
$
|
6.84
|
|
|
|
|
|
|
|
WEIGHTED AVERAGE SHARES
OUTSTANDING:
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
1,928,225
|
|
|
|
2,988,986
|
|
|
|
3,012,414
|
|
|
|
|
|
|
|
Diluted
|
|
|
1,928,225
|
|
|
|
2,988,986
|
|
|
|
3,101,180
|
|
|
|
See accompanying notes to these
combined financial statements.
F-4
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loans to
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Retained
|
|
|
stockholders
|
|
|
|
|
|
|
|
|
|
|
|
|
Additional
|
|
|
earnings
|
|
|
including
|
|
|
|
|
|
|
Common
stock
|
|
|
paid-in
|
|
|
(accumulated
|
|
|
accrued
|
|
|
|
|
|
|
Shares
|
|
|
Amount
|
|
|
capital
|
|
|
deficit)
|
|
|
interest
|
|
|
Total
|
|
|
|
|
BALANCE
,
January 1, 2004
|
|
|
560,000
|
|
|
$
|
5,600
|
|
|
$
|
5,646,429
|
|
|
$
|
(2,335,760
|
)
|
|
$
|
(444,302
|
)
|
|
$
|
2,871,967
|
|
Issuance of Approach Resources Inc.
common stock for cash
|
|
|
2,390,000
|
|
|
|
23,900
|
|
|
|
23,865,242
|
|
|
|
|
|
|
|
(3,495,000
|
)
|
|
|
20,394,142
|
|
Issuance of Approach
Oil & Gas Inc. common stock for cash
|
|
|
20,000
|
|
|
|
200
|
|
|
|
1,999,800
|
|
|
|
|
|
|
|
|
|
|
|
2,000,000
|
|
Accrual of interest on loans to
stockholders
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(124,119
|
)
|
|
|
(124,119
|
)
|
Net loss
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(266,170
|
)
|
|
|
|
|
|
|
(266,170
|
)
|
|
|
|
|
|
|
BALANCE
,
December 31, 2004
|
|
|
2,970,000
|
|
|
|
29,700
|
|
|
|
31,511,471
|
|
|
|
(2,601,930
|
)
|
|
|
(4,063,421
|
)
|
|
|
24,875,820
|
|
Issuance of Approach
Oil & Gas Inc. common stock for cash
|
|
|
30,000
|
|
|
|
300
|
|
|
|
2,990,459
|
|
|
|
|
|
|
|
|
|
|
|
2,990,759
|
|
Accrual of interest on loans to
stockholders
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(234,900
|
)
|
|
|
(234,900
|
)
|
Net income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
12,058,248
|
|
|
|
|
|
|
|
12,058,248
|
|
|
|
|
|
|
|
BALANCE
,
December 31, 2005
|
|
|
3,000,000
|
|
|
|
30,000
|
|
|
|
34,501,930
|
|
|
|
9,456,318
|
|
|
|
(4,298,321
|
)
|
|
|
39,689,927
|
|
Purchase and cancellation of
Approach Resources Inc. common stock
|
|
|
(34,615
|
)
|
|
|
(346
|
)
|
|
|
(1,330,616
|
)
|
|
|
|
|
|
|
333,499
|
|
|
|
(997,463
|
)
|
Issuance of Approach
Oil & Gas Inc. common stock for cash
|
|
|
65,000
|
|
|
|
650
|
|
|
|
6,497,685
|
|
|
|
|
|
|
|
|
|
|
|
6,498,335
|
|
Issuance of Approach
Oil & Gas Inc. common stock for conversion of
stockholder note
|
|
|
35,000
|
|
|
|
350
|
|
|
|
3,499,650
|
|
|
|
|
|
|
|
|
|
|
|
3,500,000
|
|
Stock option cancellation payment
|
|
|
|
|
|
|
|
|
|
|
(273,547
|
)
|
|
|
|
|
|
|
|
|
|
|
(273,547
|
)
|
Stock-based compensation expense
|
|
|
|
|
|
|
|
|
|
|
33,612
|
|
|
|
|
|
|
|
|
|
|
|
33,612
|
|
Accrual of interest on loans to
stockholders, net of related income tax
|
|
|
|
|
|
|
|
|
|
|
138,286
|
|
|
|
|
|
|
|
(219,502
|
)
|
|
|
(81,216
|
)
|
Net income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
21,201,905
|
|
|
|
|
|
|
|
21,201,905
|
|
|
|
|
|
|
|
BALANCE
,
December 31, 2006
|
|
|
3,065,385
|
|
|
$
|
30,654
|
|
|
$
|
43,067,000
|
|
|
$
|
30,658,223
|
|
|
$
|
(4,184,324
|
)
|
|
$
|
69,571,553
|
|
|
|
See accompanying notes to these
combined financial statements.
F-5
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the years
ended December 31,
|
|
|
|
2004
|
|
|
2005
|
|
|
2006
|
|
|
|
|
OPERATING ACTIVITIES:
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$
|
(266,170
|
)
|
|
$
|
12,058,248
|
|
|
$
|
21,201,905
|
|
Adjustments to reconcile net income
(loss) to net cash provided by operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Depletion, depreciation and
amortization
|
|
|
1,223,340
|
|
|
|
8,006,054
|
|
|
|
14,540,570
|
|
Amortization of loan origination
fees
|
|
|
833
|
|
|
|
47,123
|
|
|
|
72,335
|
|
Accretion of discount on asset
retirement obligations
|
|
|
582
|
|
|
|
4,974
|
|
|
|
10,299
|
|
Change in fair value of commodity
derivatives
|
|
|
|
|
|
|
4,163,098
|
|
|
|
(8,668,094
|
)
|
Impairment of non producing
leasehold costs
|
|
|
|
|
|
|
|
|
|
|
558,446
|
|
Exploration expense
|
|
|
|
|
|
|
902,336
|
|
|
|
1,419,375
|
|
Stock-based compensation expense
|
|
|
|
|
|
|
|
|
|
|
33,612
|
|
Deferred income taxes
|
|
|
|
|
|
|
6,447,916
|
|
|
|
11,101,191
|
|
Interest earned on loans to
stockholders
|
|
|
(124,119
|
)
|
|
|
(234,900
|
)
|
|
|
|
|
Changes in operating assets and
liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Accounts receivable
|
|
|
(5,881,208
|
)
|
|
|
(9,778,543
|
)
|
|
|
7,389,365
|
|
Prepaid expenses and other current
assets
|
|
|
(166,444
|
)
|
|
|
(67,896
|
)
|
|
|
220,659
|
|
Accounts payable
|
|
|
8,314,994
|
|
|
|
12,128,687
|
|
|
|
(13,016,692
|
)
|
Oil and gas payables
|
|
|
1,375,519
|
|
|
|
5,269,060
|
|
|
|
(1,704,164
|
)
|
Accrued liabilities
|
|
|
50,160
|
|
|
|
1,358,036
|
|
|
|
951,067
|
|
|
|
|
|
|
|
Cash provided by operating
activities
|
|
|
4,527,487
|
|
|
|
40,304,193
|
|
|
|
34,109,874
|
|
INVESTING ACTIVITIES:
|
|
|
|
|
|
|
|
|
|
|
|
|
Advances under note receivable
|
|
|
(1,587,820
|
)
|
|
|
(4,151,773
|
)
|
|
|
|
|
Payments received under note
receivable
|
|
|
41,760
|
|
|
|
5,697,833
|
|
|
|
|
|
Additions to oil and gas properties
|
|
|
(25,165,644
|
)
|
|
|
(73,445,231
|
)
|
|
|
(59,156,557
|
)
|
Additions to other property and
equipment, net
|
|
|
(147,516
|
)
|
|
|
(39,950
|
)
|
|
|
(32,139
|
)
|
|
|
|
|
|
|
Cash used in investing activities
|
|
|
(26,859,220
|
)
|
|
|
(71,939,121
|
)
|
|
|
(59,188,696
|
)
|
FINANCING ACTIVITIES:
|
|
|
|
|
|
|
|
|
|
|
|
|
Proceeds from issuance of common
stock
|
|
|
22,394,142
|
|
|
|
2,990,759
|
|
|
|
6,498,335
|
|
Borrowings under credit facility,
net
|
|
|
100,000
|
|
|
|
29,325,000
|
|
|
|
18,194,000
|
|
Purchase of common stock
|
|
|
|
|
|
|
|
|
|
|
(997,463
|
)
|
Borrowing from stockholder
|
|
|
|
|
|
|
|
|
|
|
3,500,000
|
|
Stock option cancellation payment
|
|
|
|
|
|
|
|
|
|
|
(273,547
|
)
|
Income taxes on interest income
from loans to stockholders
|
|
|
|
|
|
|
|
|
|
|
(81,216
|
)
|
Loan origination fees
|
|
|
(20,000
|
)
|
|
|
(116,951
|
)
|
|
|
(69,509
|
)
|
|
|
|
|
|
|
Cash provided by financing
activities
|
|
|
22,474,142
|
|
|
|
32,198,808
|
|
|
|
26,770,600
|
|
|
|
|
|
|
|
CHANGE IN CASH AND CASH
EQUIVALENTS
|
|
|
142,409
|
|
|
|
563,880
|
|
|
|
1,691,778
|
|
CASH AND CASH
EQUIVALENTS
, beginning
of year
|
|
|
2,513,174
|
|
|
|
2,655,583
|
|
|
|
3,219,463
|
|
|
|
|
|
|
|
CASH AND CASH
EQUIVALENTS
, end of year
|
|
$
|
2,655,583
|
|
|
$
|
3,219,463
|
|
|
$
|
4,911,241
|
|
|
|
|
|
|
|
SUPPLEMENTAL DISCLOSURE OF CASH
FLOW INFORMATION:
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash paid for interest
|
|
$
|
1,935
|
|
|
$
|
600,070
|
|
|
$
|
3,268,593
|
|
|
|
|
|
|
|
Cash paid for income taxes
|
|
$
|
|
|
|
$
|
|
|
|
$
|
2,148
|
|
|
|
|
|
|
|
SUPPLEMENTAL DISCLOSURE OF
NON-CASH TRANSACTION:
|
|
|
|
|
|
|
|
|
|
|
|
|
Conversion of stockholder note into
common stock
|
|
$
|
|
|
|
$
|
|
|
|
$
|
3,500,000
|
|
|
|
See accompanying notes to these
combined financial statements.
F-6
|
|
1.
|
Summary of
significant accounting policies
|
Organization and
nature of operations
Approach Resources Inc. (ARI) is a Delaware
corporation formed September 13, 2002. ARI has three wholly
owned subsidiaries. In November 2004, Approach Oil &
Gas Inc. (AOG) and three wholly owned subsidiaries
were formed and acquired leasehold positions in Kentucky and New
Mexico. Collectively, ARI and AOG and their respective
subsidiaries are referred to as we, our,
Approach or the Company. We are engaged
in the acquisition, development and operation of oil and gas
properties located in Texas, Kentucky and New Mexico. Our plans
are to explore for or acquire and develop oil and gas properties
primarily in the United States.
Basis of
combination and presentation
The accompanying combined financial statements include the
accounts of ARI and its subsidiaries and AOG and its
subsidiaries. These entities are related due to their common
ownership. All significant intercompany transactions and
balances have been eliminated.
The combination of ARI and AOG is to occur simultaneously with
the closing of an initial public offering with Approach
Resources Inc. as the surviving entity.
Cash and cash
equivalents
We consider all highly liquid debt instruments purchased with a
remaining maturity of three months or less to be cash
equivalents.
Financial
instruments
The carrying amounts of financial instruments including cash and
cash equivalents, accounts receivable, notes receivable,
accounts payable and accrued liabilities and long-term debt
approximate fair value, as of December 31, 2005 and 2006.
Oil and gas
properties
We follow the successful efforts method of accounting for our
oil and gas producing activities. Costs incurred by the Company
related to the acquisition of oil and gas properties and the
cost of drilling all development wells and successful
exploratory wells are capitalized. Costs incurred to maintain
wells and related equipment and lease and well operating costs
are charged to expense as incurred. Gains and losses arising
from sales of properties are included in income. Unproved
properties are assessed periodically for possible impairment. No
such impairment was recorded during either year ended
December 31, 2004 or 2005. An impairment of $558,446 was
recorded in 2006 for unproved properties. The Company had
unproved properties amounting to $1,787,422 and $5,597,411 as of
December 31, 2005 and 2006, respectively.
Capitalized amounts attributable to proved oil and gas
properties are depleted by the unit-of-production method based
on proved reserves. Depreciation and depletion expense for oil
and
F-7
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
gas producing property and related equipment was $1,193,562,
$7,951,256 and $14,476,643 for the years ended December 31,
2004, 2005 and 2006, respectively.
Capitalized costs are evaluated for impairment based on an
analysis of undiscounted future net cash flows in accordance
with Financial Accounting Standards Board Statement
No. 144,
Accounting for the Impairment or Disposal of
Long-Lived Assets
. If impairment is indicated, the asset is
written down to its estimated fair value based on expected
discounted future net cash flows. No impairment was recorded
during the years ended December 31, 2004, 2005 or 2006.
Revenue and
accounts receivable
We recognize revenue for our production when the quantities are
delivered to or collected by the respective purchaser. Prices
for such production are defined in sales contracts and are
readily determinable based on certain publicly available
indices. All transportation costs are accounted for as a
reduction of oil and natural gas sales revenue.
Accounts receivable, joint interest owners, consist of
uncollateralized joint interest owner obligations due within
30 days of the invoice date. Accounts receivable, oil and
gas sales, consist of uncollateralized accrued revenues due
under normal trade terms, generally requiring payment within 30
to 60 days of production. No interest is charged on
past-due balances. Payments made on all accounts receivable are
applied to the earliest unpaid items. We review receivables
periodically and reduce the carrying amount by a valuation
allowance that reflects our best estimate of the amount that may
not be collectible. No such allowance was considered necessary
at December 31, 2005 or 2006.
Concentrations of
credit risk
For the years ended December 31, 2004, 2005 and 2006, we
sold substantially all of our oil and gas produced to four
purchasers. We do not believe that the loss of any one of these
purchasers would have a material adverse effect on our results
of operations or cash flows because we believe we could readily
locate other purchasers.
Other
property
Furniture, fixtures and equipment are carried at cost.
Depreciation of furniture, fixtures and equipment is provided
using the straight-line method over estimated useful lives
ranging from three to ten years. Gain or loss on retirement or
sale or other disposition of assets is included in income in the
period of disposition. Depreciation expense for other property
and equipment was $29,778, $54,798 and $63,927 for the years
ended December 31, 2004, 2005 and 2006, respectively.
Note
receivable
In conjunction with a farmout agreement, a full recourse
revolving promissory note was entered into for the benefit of a
working interest owner to fund its costs incurred drilling wells
under the farmout agreement. Effective December 31, 2005,
we purchased the working interest for $10,500,000 by the
retirement of the note receivable and accrued interest of
approximately
F-8
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
$3,500,000 and the payment of approximately $7,000,000 in
January 2006. The note provided for interest at 6 percent
and was collateralized by the working interest in the wells
drilled under the farmout agreement.
Income
taxes
We follow the provisions of Financial Account Standard
No. 109,
Accounting for Income Taxes
(FAS 109). Under the asset and liability
method of FAS 109, deferred tax assets and liabilities are
recognized for the estimated future tax consequences
attributable to the differences between the financial statement
carrying amounts of existing assets and liabilities and their
respective tax bases. Deferred tax assets and liabilities are
measured using the tax rate in effect for the year in which
those temporary differences are expected to be recovered or
settled. Under FAS 109, the effect of a change in tax rates
on deferred tax assets and liabilities is recognized in income
in the year of the enacted tax rate change.
Derivative
activity
All derivative instruments are recorded on the balance sheet at
fair value. Changes in the derivatives fair value are
currently recognized in the statement of operations unless
specific hedge accounting criteria are met. For qualifying cash
flow hedges, the gain or loss on the derivative is deferred in
accumulated other comprehensive income (loss) to the extent the
hedge is effective. The ineffective portion of the hedge is
recognized immediately in the statement of operations. Gains and
losses on hedging instruments included in cumulative other
comprehensive income (loss) are reclassified to oil and natural
gas sales revenue in the period that the related production is
delivered. Derivative contracts that do not qualify for hedge
accounting treatment are recorded as derivative assets and
liabilities at fair value in the balance sheet, and the
associated unrealized gains and losses are recorded as current
income or expense in the statement of operations.
Historically, we have not designated our derivative instruments
as cash-flow hedges. We record our open derivative instruments
at fair value on our combined balance sheets as either
unrealized gains or losses on commodity derivatives. We record
changes in such fair value in earnings on our combined
statements of operations under the caption entitled change
in fair value of commodity derivatives.
Although we have not designated our derivative instruments as
cash-flow hedges, we use those instruments to reduce our
exposure to fluctuations in commodity prices related to our
natural gas and oil production. Accordingly, we record realized
gains and losses under those instruments in natural gas and oil
sales revenues on our combined statements of operations. For the
years ended December 31, 2005 and 2006, we recognized an
unrealized loss of $4,163,098 and an unrealized gain of
$8,668,094 from changes in the fair values of commodity
derivatives, respectively. See Note 7 for further
discussion of our derivative activity.
F-9
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
Comprehensive
income (loss)
We had no elements of comprehensive income other than net income
(loss) during the years ended December 31, 2004, 2005 or
2006.
Use of estimates
and certain significant estimates
The preparation of our financial statements in conformity with
U.S. generally accepted accounting principles requires us
to make estimates and assumptions that affect the amounts
reported in these financial statements and accompanying notes.
Actual results could differ from those estimates. Significant
assumptions are required in the valuation of proved oil and gas
reserves, which as described above may affect the amount at
which oil and gas properties are recorded. The estimate of asset
retirement obligations also utilizes significant assumptions. It
is at least reasonably possible these estimates could be revised
in the near term and these revisions could be material.
Stock-based
compensation
Prior to January 1, 2006, we accounted for stock option
awards granted under our 2003 Stock Option Plan in accordance
with the recognition and measurement provisions of Accounting
Principles Board Opinion No. 25,
Accounting for Stock
Issued to Employees
(APB 25) and related
Interpretations, as permitted by Statement of Financial
Accounting Standards No. 123,
Accounting for Stock-Based
Compensation
(SFAS No. 123).
Share-based employee compensation expense was not recognized in
the Companys combined statements of operations prior to
January 1, 2006, as all stock option awards granted had an
exercise price equal to or greater than the estimated fair
market value of the common stock on the date of the grant. As
permitted by SFAS No. 123, we reported pro-forma
disclosures presenting results and earnings (loss) per share as
if we had used the fair value recognition provisions of
SFAS No. 123 in the Notes to Combined Financial
Statements. Share-based compensation related to non-employees
and modifications of options granted were accounted for based on
the fair value of the related stock or options in accordance
with SFAS No. 123 and its interpretations.
Effective January 1, 2006, we adopted the provisions of
Statement of Financial Accounting Standards No. 123
(revised 2004),
Share-Based Payment
(SFAS No. 123(R)), which requires the
measurement and recognition of compensation expense for all
share-based payment awards to employees and directors based on
estimated fair values. We adopted SFAS No. 123(R) using the
modified prospective transition method. In accordance with the
modified prospective application provisions of
SFAS No. 123(R), compensation cost for the portion of
awards that were outstanding as of January 1, 2006, for
which the requisite service was not rendered, are recognized as
the requisite service is rendered, based on the grant date fair
value estimated in accordance with the provisions of
SFAS No. 123(R). Additionally, compensation costs for
awards granted after January 1, 2006 are recognized over
the requisite service period based on the grant-date fair value.
In accordance with the modified prospective transition method,
our combined financial statements for prior periods have not
been restated to reflect the impact of
SFAS No. 123(R). In connection with the adoption of
SFAS 123(R) on January 1, 2006, we recorded
compensation expense of $33,612 for options vesting during 2006.
F-10
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
Asset retirement
obligation
Our asset retirement obligations relate to future plugging and
abandonment expenses on oil and gas properties. The following
table shows the changes in the balance of the ARO during the
years ended December 31, 2006 and 2005:
|
|
|
|
|
|
|
|
|
|
|
|
|
2005
|
|
|
2006
|
|
|
|
|
Asset retirement obligation,
January 1
|
|
$
|
99,312
|
|
|
$
|
107,230
|
|
Changes in assumptions
|
|
|
(63,375
|
)
|
|
|
(13,612
|
)
|
Liabilities incurred during the
year
|
|
|
66,319
|
|
|
|
43,727
|
|
Liabilities settled during the year
|
|
|
|
|
|
|
|
|
Accretion expense
|
|
|
4,974
|
|
|
|
10,299
|
|
|
|
|
|
|
|
Asset retirement obligation,
December 31
|
|
$
|
107,230
|
|
|
$
|
147,644
|
|
|
|
Based on the expected timing of payments, the full asset
retirement obligation is classified as non-current.
Earnings (loss)
per common share
In accordance with SFAS No. 128,
Earnings Per
Share
, we report basic earnings (loss) per common share,
which excludes the effect of potentially dilutive securities,
and diluted earnings (loss) per common share, which includes the
effect of all potentially dilutive securities unless their
impact is anti-dilutive. Stock options were the only dilutive
securities outstanding during the years ended December 31,
2004, 2005 and 2006. During the years ended December 31,
2004 and 2005, the effects of options to acquire 125,000 common
shares were excluded from diluted weighted average shares
outstanding because their effects would have been anti-dilutive.
The following is a reconciliation of basic and diluted weighted
average shares outstanding for the year ended December 31,
2006:
|
|
|
|
|
Weighted average shares
outstanding, basic
|
|
|
3,012,414
|
Dilutive effect of stock options
|
|
|
88,766
|
|
|
|
|
Weighted average shares
outstanding, diluted
|
|
|
3,101,180
|
|
|
New accounting
pronouncements
In September 2006, Statement of Financial Accounting Standards
No. 157,
Fair Value Measurements
(SFAS 157), was issued. SFAS 157
provides guidance for using fair value to measure assets and
liabilities. It applies whenever other standards require or
permit assets or liabilities to be measured at fair value, but
it does not expand the use of fair value in any new
circumstances. The provisions of SFAS 157 are effective for
financial statements issued for fiscal years beginning after
November 15, 2007. The effect of adopting SFAS 157 has
not been determined, but it is not expected to have a
significant effect on our reported financial position or
earnings.
F-11
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
In February 2007, SFAS No. 159,
The Fair Value
Option for Financial Assets and Financial Liabilities -Including
an Amendment of FASB Statement No. 115
(SFAS 159), was issued. SFAS 159 permits
an entity to choose to measure many financial instruments and
certain other items at fair value. The fair value option
established by SFAS 159 permits all entities to choose to
measure eligible items at fair value at specified election
dates. Unrealized gains and losses on items for which the fair
value option has been elected are to be recognized in earnings
at each subsequent reporting date. SFAS 159 is effective
for financial statements issued for fiscal years beginning after
November 15, 2007. The effect of adopting SFAS 159 has
not been determined, but it is not expected to have a
significant effect on reported financial position or earnings.
In July 2006, FASB Interpretation No. 48,
Accounting for
Uncertainty in Income Taxesan Interpretation of FASB
Statement No. 109
(FIN 48), was
issued. FIN 48 clarifies financial statement recognition
and disclosure requirements for uncertain tax positions taken or
expected to be taken in a tax return. Financial statement
recognition of the tax position is dependent on an assessment of
a 50% or greater likelihood that the tax position will be
sustained upon examination, based on the technical merits of the
position. The provisions of FIN 48 must be adopted as of
the beginning of fiscal years beginning after December 15,
2006, with the cumulative effect reported as an adjustment to
retained earnings at the adoption date. The effect of adoption
of FIN 48 has not been determined, but is not expected to
have a significant effect on our reported financial position or
earnings.
In September 2006, the SEC staff issued Staff Accounting
Bulletin Topic 1N,
Financial StatementsConsidering
the Effects of Prior Year Misstatements when Quantifying
Misstatements in Current Year Financial Statements
(SAB 108). SAB 108 provides guidance on how
prior year misstatements should be evaluated when determining
the materiality of misstatements in current year financial
statements. SAB 108 requires materiality to be determined
by considering the effect of prior year misstatements on both
the current year balance sheet and statement of operations, with
consideration of their carryover and reversing effects.
SAB 108 also addresses how to correct material
misstatements. The provisions of SAB 108 are effective for
financial statements issued for fiscal years ending after
November 15, 2006. SAB 108 did not have any effect on
our reported financial position or earnings.
2. Loans
to stockholders and stockholder notes payable
During each of the years ended December 31, 2003 and 2004,
in exchange for cash and notes receivable from employees and
entities owned by or affiliated with management, we issued
450,000 shares of common stock. In January 2007, the
remaining notes and accrued interest were repaid in exchange for
84,550 shares of common stock held by management. The notes
provided for interest at 6 percent and were payable upon
the earlier of December 31, 2008, the registration of the
underlying common stock, or upon a merger with another entity or
upon a divestiture of our assets. The notes were collateralized
by the underlying common stock purchased and are reported in the
accompanying balance sheet as loans to stockholders including
accrued interest, reducing stockholders equity. Interest
earned is reported net of related tax income as a component of
additional paid-in capital in the accompanying statement
F-12
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
of changes in stockholders equity. The following is a
summary of the balance of principal and interest outstanding
under the notes receivable at December 31:
|
|
|
|
|
|
|
|
|
|
2005
|
|
2006
|
|
|
Principal
|
|
$
|
3,915,000
|
|
$
|
3,613,850
|
Accrued interest
|
|
|
383,321
|
|
|
570,474
|
|
|
|
|
|
|
Total
|
|
$
|
4,298,321
|
|
$
|
4,184,324
|
|
|
In 2006, AOG borrowed $3,500,000 from a stockholder to fund the
acquisition of leaseholds in Kentucky. The terms of the
borrowing provided for interest at 6 percent and was due on
demand. The borrowing was settled through the issuance of
35,000 shares of AOG common stock.
3. Line
of credit
We have a revolving loan agreement with Frost Bank (the
Agreement), which provides a borrowing base
determined by the bank based on oil and gas reserve values. As
of December 31, 2006, the borrowing base was $60,000,000.
Borrowings outstanding under the Agreement at December 31,
2005 and 2006 were $29,425,000 and $47,619,000, respectively. In
February 2007, the line of credit was raised to $100,000,000 and
the borrowing base was increased to $75,000,000. The borrowings
bear interest based on the banks prime rate or the LIBOR.
The interest rate applicable to our outstanding borrowings was
approximately 8.25 percent as of December 31, 2006.
Principal payments are not required until January 31, 2008,
the final maturity date of the Agreement, at which time any
outstanding loan balances shall be due and payable in full. In
addition, the Agreement requires payment of a quarterly fee
equal to three-eights of one percent (0.375%) of the unused
portion of the borrowing base. The borrowings are collateralized
by substantially all of our oil and gas properties. The
Agreement contains various covenants, the most restrictive of
which requires us to maintain a modified current ratio of at
least one. We were in compliance with the covenants at
December 31, 2006.
We also have outstanding unused letters of credit under the
Agreement totaling $300,000, which reduce amounts available for
borrowing under the Agreement.
F-13
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
Stockholders equity on our combined balance sheets as of
December 31, 2005 and 2006 includes the equity accounts of
ARI and AOG. Details of authorized and outstanding shares and
their related par values are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
Approach
|
|
Approach
|
|
|
|
|
Resources
Inc.
|
|
Oil
& Gas Inc.
|
|
Combined
|
|
|
PREFERRED STOCK:
|
|
|
|
|
|
|
|
|
|
Par value, per share
|
|
$
|
0.01
|
|
$
|
0.01
|
|
$
|
0.01
|
Shares authorized
|
|
|
1,000,000
|
|
|
100,000
|
|
|
1,100,000
|
Shares issued and outstanding at:
|
|
|
|
|
|
|
|
|
|
December 31, 2005
|
|
|
|
|
|
|
|
|
|
December 31, 2006
|
|
|
|
|
|
|
|
|
|
COMMON STOCK:
|
|
|
|
|
|
|
|
|
|
Par value, per share
|
|
$
|
0.01
|
|
$
|
0.01
|
|
$
|
0.01
|
Shares authorized
|
|
|
4,000,000
|
|
|
1,000,000
|
|
|
5,000,000
|
Shares issued and outstanding at:
|
|
|
|
|
|
|
|
|
|
December 31, 2005
|
|
|
2,950,000
|
|
|
50,000
|
|
|
3,000,000
|
December 31, 2006
|
|
|
2,915,385
|
|
|
150,000
|
|
|
3,065,385
|
|
|
5. Stock
options
In January 2003, our stockholders approved the 2003 Stock Option
Plan (the Plan). Under the Plan, we may grant
options to selected employees and directors for up to
150,000 shares of common stock at a price not less than the
fair market value at the date of the grant, as determined by the
Board of Directors. The options granted under the Plan generally
have a term of ten years and vest over a three year period.
As discussed in Note 1,
Significant Accounting
PoliciesShared-Based Compensation
, effective
January 1, 2006, we adopted the fair value recognition
provisions of SFAS No. 123(R), using the modified
prospective transition method. Share-based compensation expense
resulting from the adoption of SFAS No. 123(R)
amounted to $33,612 for the year ended December 31, 2006.
Such amount represents the estimated fair value of options for
which the requisite service period elapsed during 2006. There
was no tax benefit recognized in relation to this change.
F-14
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
The following table summarizes stock options outstanding and
activity as of and for the year ended December 31, 2006:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
average
|
|
|
|
|
|
Weighted
|
|
remaining
|
|
|
|
|
|
average
|
|
contractual
|
|
|
|
|
|
exercise
|
|
term
|
|
|
Shares
|
|
|
price
|
|
(in
years)
|
|
|
Outstanding at January 1, 2006
|
|
|
125,000
|
|
|
$
|
10.00
|
|
|
|
Granted
|
|
|
|
|
|
$
|
|
|
|
|
Canceled
|
|
|
(9,615
|
)
|
|
$
|
10.00
|
|
|
|
Exercised
|
|
|
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding at December 31,
2006
|
|
|
115,385
|
|
|
$
|
10.00
|
|
|
7.63
|
|
|
|
|
|
|
Exercisable (fully vested) at
December 31, 2006
|
|
|
115,385
|
|
|
$
|
10.00
|
|
|
7.63
|
|
|
There have been no exercises of options through
December 31, 2006. Additionally, the Plan is a qualified
plan under the Internal Revenue Code. Accordingly, we do not
anticipate realizing any tax deductions related to the exercise
of stock options. Upon exercise, we expect to issue the full
amount of shares exercisable per the term of the options from
new shares. We have no plans to repurchase those shares in the
future.
Total unrecognized share-based compensation expense from
unvested stock options as of December 31, 2006 was zero
since all options are fully vested at December 31, 2006.
During the year ended December 31, 2006, we paid $273,547
in cash to cancel the vested options held by an employee who
voluntarily resigned. Such amount has been recorded as a
reduction to additional paid in capital as the payment did not
exceed the estimated fair value of the options at the time of
the cancellation.
F-15
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
6. Income
taxes
Our provision for income taxes comprised the following during
the years ended December 31:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2004
|
|
2005
|
|
2006
|
|
|
|
|
Current:
|
|
|
|
|
|
|
|
|
|
|
Federal
|
|
$
|
|
|
$
|
509,402
|
|
$
|
549,864
|
|
State
|
|
|
|
|
|
70,598
|
|
|
105,504
|
|
|
|
|
|
|
|
Total current
|
|
|
|
|
|
580,000
|
|
|
655,368
|
|
Deferred:
|
|
|
|
|
|
|
|
|
|
|
Federal
|
|
|
|
|
|
5,663,074
|
|
|
11,242,568
|
|
State
|
|
|
|
|
|
784,842
|
|
|
(141,377
|
)
|
|
|
|
|
|
|
Total deferred
|
|
|
|
|
|
6,447,916
|
|
|
11,101,191
|
|
|
|
|
|
|
|
Provision for income taxes
|
|
$
|
|
|
$
|
7,027,916
|
|
$
|
11,756,559
|
|
|
|
Total income tax expense (benefit) differed from the amounts
computed by applying the U.S. Federal statutory tax rates
to pre-tax income for the years ended December 31, 2006,
2005 and 2004 as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2004
|
|
|
2005
|
|
|
2006
|
|
|
|
|
Statutory tax (benefit) at 34%
|
|
$
|
(90,498
|
)
|
|
$
|
6,489,796
|
|
|
$
|
11,205,149
|
|
State taxes (benefit), net of
federal impact
|
|
|
(7,905
|
)
|
|
|
568,635
|
|
|
|
989,337
|
|
Changes in enacted rates
|
|
|
|
|
|
|
|
|
|
|
(1,076,794
|
)
|
Other differences
|
|
|
(25,597
|
)
|
|
|
(249,515
|
)
|
|
|
(173,133
|
)
|
Change in valuation allowance
|
|
|
124,000
|
|
|
|
219,000
|
|
|
|
812,000
|
|
|
|
|
|
|
|
|
|
$
|
|
|
|
$
|
7,027,916
|
|
|
$
|
11,756,559
|
|
|
|
In May 2006, the State of Texas enacted a margin tax which will
require us to pay a tax of 1.0% on our taxable
margin, as defined in the law, based on our operating
results beginning January 1, 2007. The margin to which the
tax rate will be applied generally will be calculated as our
gross revenues for federal income tax purposes less the cost of
goods sold, as defined for Texas margin tax purposes. Cost of
goods sold includes the following expenses that are related to
our production of goods: our lease operating expenses,
production taxes, depletion and depreciation expense, and labor
costs. Most of our operations are within the State of Texas.
Under the provisions of Statement of Financial Accounting
Standards No. 109,
Accounting for Income Taxes
, we
are required to record the effects on deferred taxes for a
change in tax rates or tax law in the period which includes the
enactment date. Previously, our results of operations were
subject to the franchise tax in Texas at a rate of 4.5%, before
consideration of federal benefits of those state taxes.
Temporary differences between book and tax income related to our
oil and gas properties will affect our computation of the Texas
margin tax, and we have
F-16
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
reduced our deferred tax liabilities by approximately $1,076,000
as of December 31, 2006 as the result of this change.
Deferred tax assets and liabilities are the result of temporary
differences between the financial statement carrying values and
tax bases of assets and liabilities. Our net deferred tax assets
and liabilities are recorded as a long-term liability of
$6,447,916 and $17,549,107 at December 31, 2005 and 2006,
respectively. Significant components of net deferred tax assets
and liabilities are:
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31,
|
|
|
|
2005
|
|
|
2006
|
|
|
|
|
Deferred tax assets:
|
|
|
|
|
|
|
|
|
Difference in depreciation and
capitalization methodsfurniture, fixtures and equipment
|
|
$
|
33,300
|
|
|
$
|
28,017
|
|
Net operating loss carryforwards
|
|
|
941,000
|
|
|
|
1,805,000
|
|
Unrealized loss on commodity
derivatives
|
|
|
1,457,084
|
|
|
|
|
|
Other
|
|
|
23,000
|
|
|
|
|
|
|
|
|
|
|
|
Total deferred tax assets
|
|
|
2,454,384
|
|
|
|
1,833,017
|
|
Less: valuation allowance
|
|
|
(783,000
|
)
|
|
|
(1,595,000
|
)
|
|
|
|
|
|
|
Net deferred tax assets
|
|
|
1,671,384
|
|
|
|
238,017
|
|
Deferred tax liability:
|
|
|
|
|
|
|
|
|
Difference in depreciation,
depletion and capitalization methodsoil and gas properties
|
|
|
(8,119,300
|
)
|
|
|
(16,225,692
|
)
|
Unrealized gain on commodity
derivatives
|
|
|
|
|
|
|
(1,561,432
|
)
|
|
|
|
|
|
|
Total deferred tax liabilities
|
|
|
(8,119,300
|
)
|
|
|
(17,787,124
|
)
|
|
|
|
|
|
|
Net deferred tax (liability)
|
|
$
|
(6,447,916
|
)
|
|
$
|
(17,549,107
|
)
|
|
|
At December 31, 2005 and 2006, AOG provided a valuation
allowance related to its deferred tax assets resulting primarily
from net operating loss carryforwards of $783,000 and
$1,595,000, respectively, based upon managements inability
to assess the amount to be realized until completion of the
merger with ARI.
Net operating loss carryforwards for tax purposes have the
following expiration dates:
|
|
|
|
|
Expiration
dates
|
|
Amounts
|
|
|
2024
|
|
$
|
1,523,000
|
2025
|
|
|
1,082,000
|
2026
|
|
|
2,603,000
|
|
|
|
|
|
|
$
|
5,208,000
|
|
|
F-17
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
7. Derivatives
In 2005, we entered into three natural gas swap agreements. The
first two swaps were for 170,000 MMBtu per month and
expired in September 2005. The other swap was for an average of
282,000 MMBtu per month through December 2006. In January
2006, we entered into a natural gas swap for approximately
257,000 MMBtu per month that expired in December 2006. In
June 2006, we entered into a natural gas swap for
100,000 MMBtu per month for the fourth quarter of 2006 and
an average of 250,000 MMBtu per month for 2007. Our oil and
gas sales revenues include realized losses of $2,924,351 and
realized gains of $6,221,927 from the swaps for the years ended
December 31, 2005 and 2006, respectively. The estimated
unrealized gain or loss from the swaps amounted to a loss of
$4,163,098 and a gain of $4,504,996 at December 31, 2005
and 2006, respectively. Changes in unrealized gains and losses
are reflected in other income (expense) on our statements of
operations. The net unrealized gain and loss is reflected as a
current asset and liability, respectively, based on the
associated production months. The fair value of commodity
derivatives were estimated based on the present value of the
difference in exchange-quoted forward price curves and
contractual settlement prices multiplied by notional quantities.
We are exposed to credit loss in the event of nonperformance by
the counterparty on our oil and gas swaps. However, we do not
anticipate nonperformance by the counterparty over the term of
the swaps.
8. Environmental
issues
We are engaged in oil and gas exploration and production and may
become subject to certain liabilities as they relate to
environmental clean up of well sites or other environmental
restoration procedures as they relate to the drilling of oil and
gas wells and the operation thereof. In connection with our
acquisition of existing or previously drilled well bores, we may
not be aware of what environmental safeguards were taken at the
time such wells were drilled or during such time the wells were
operated. Should it be determined that a liability exists with
respect to any environmental clean up or restoration, we would
be responsible for curing such a violation. No claim has been
made, nor are we aware of any liability that exists, as it
relates to any environmental clean up, restoration or the
violation of any rules or regulations relating thereto.
9. Commitments
and contingencies
We have employment agreements with our officers and selected
other employees. These agreements are automatically renewed for
successive terms of one year unless employment is terminated at
the end of the term by written notice given to the employee not
less than 60 days prior to the end of such term. Our
maximum commitment under the employment agreements, which would
apply if the employees covered by these agreements were all
terminated without cause, is approximately $1,400,000 at
December 31, 2006.
We lease our office space in Fort Worth, Texas under a
non-cancelable agreement that expires on May 31, 2009. We
also have non-cancelable operating lease commitments related to
office
F-18
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
equipment that expire in 2009 and 2011. The following is a
schedule by years of future minimum rental payments required
under our operating lease arrangements as of December 31,
2006:
|
|
|
|
|
2007
|
|
$
|
125,824
|
2008
|
|
|
127,481
|
2009
|
|
|
56,385
|
Remainder
|
|
|
4,632
|
|
|
|
|
Total
|
|
$
|
314,322
|
|
|
Rent expense under our lease arrangements amounted to $132,247,
$129,657, and $136,532 for the years ended December 31,
2004, 2005 and 2006, respectively.
In April 2007, we signed a five-year lease for approximately
13,000 square feet of office space in Fort Worth,
Texas. That lease calls for minimum monthly rent payments of
approximately $20,000 from August 2007 through October 2012.
Litigation
We are involved in various claims and legal actions arising in
the normal course of business. In our opinion, the resolution of
these matters is not expected to have a material adverse effect
on our financial position or results of operations.
10. Oil
and gas producing activities
Set forth below is certain information regarding the costs
incurred for oil and gas property acquisition, development and
exploration activities (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
For the years
ended December 31,
|
|
|
2004
|
|
2005
|
|
2006
|
|
|
Property acquisition costs:
|
|
|
|
|
|
|
|
|
|
Unproved properties
|
|
$
|
552
|
|
$
|
369
|
|
$
|
4,071
|
Proved properties
|
|
|
|
|
|
11,592
|
|
|
356
|
Exploration costs
|
|
|
2,396
|
|
|
2,249
|
|
|
1,640
|
Development costs
|
|
|
24,863
|
|
|
60,087
|
|
|
55,203
|
|
|
|
|
|
|
Total costs incurred
|
|
$
|
27,811
|
|
$
|
74,297
|
|
$
|
61,270
|
|
|
F-19
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
Set forth below is certain information regarding the results of
operations for oil and gas producing activities (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the years
ended December 31,
|
|
|
|
2004
|
|
|
2005
|
|
|
2006
|
|
|
|
|
Revenues
|
|
$
|
5,813
|
|
|
$
|
40,747
|
|
|
$
|
53,408
|
|
Production costs
|
|
|
(586
|
)
|
|
|
(4,885
|
)
|
|
|
(5,624
|
)
|
Exploration expenses
|
|
|
(2,396
|
)
|
|
|
(734
|
)
|
|
|
(1,640
|
)
|
Depletion
|
|
|
(1,223
|
)
|
|
|
(8,006
|
)
|
|
|
(14,541
|
)
|
Income tax expenses
|
|
|
(1,157
|
)
|
|
|
(10,169
|
)
|
|
|
(12,221
|
)
|
|
|
|
|
|
|
Results of operations
|
|
$
|
451
|
|
|
$
|
16,953
|
|
|
$
|
19,382
|
|
|
|
11. Disclosures
about oil and gas producing activities (unaudited):
The estimates of proved reserves and related valuations for the
years ended December 31, 2004, 2005 and 2006 were based
upon the reports prepared by Cawley, Gillespie &
Associates, Inc., independent petroleum engineers (for 2004 and
2005), and by DeGolyer and MacNaughton, Inc., independent
petroleum engineers (for 2006). Each years estimate of
proved reserves and related valuations was prepared in
accordance with the provisions of Statement of Financial
Accounting Standards No. 69
(SFAS No. 69),
Disclosures about Oil
and Gas Producing Activities
. Estimates of proved reserves
are inherently imprecise and are continually subject to revision
based on production history, results of additional exploration
and development, price changes and other factors.
F-20
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
All of our oil and natural gas reserves are attributable to
properties within the United States. A summary of
Approachs changes in quantities of proved oil and natural
gas reserves for the years ended December 31, 2004, 2005
and 2006, are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural
gas
|
|
|
Oil
|
|
|
|
|
|
(MMcf)
|
|
|
(MBbl)
|
|
|
BalanceJanuary 1, 2004
|
|
|
|
|
|
|
|
|
Extensions and discoveries
|
|
|
58,555
|
|
|
|
361
|
|
Sales of minerals in place
|
|
|
|
|
|
|
|
|
Purchases of minerals in place
|
|
|
|
|
|
|
|
|
Production
|
|
|
(858
|
)
|
|
|
(8
|
)
|
Revisions to previous estimates
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
BalanceDecember 31, 2004
|
|
|
57,697
|
|
|
|
353
|
|
Extensions and discoveries
|
|
|
2,755
|
|
|
|
26
|
|
Sales of minerals in place
|
|
|
|
|
|
|
|
|
Purchases of minerals in place
|
|
|
6,400
|
|
|
|
68
|
|
Production
|
|
|
(4,666
|
)
|
|
|
(58
|
)
|
Revisions to previous estimates
|
|
|
40,219
|
|
|
|
697
|
|
|
|
|
|
|
|
BalanceDecember 31, 2005
|
|
|
102,405
|
|
|
|
1,086
|
|
Extensions and discoveries
|
|
|
15,655
|
|
|
|
339
|
|
Sales of minerals in place
|
|
|
|
|
|
|
|
|
Purchases of minerals in place
|
|
|
|
|
|
|
|
|
Production
|
|
|
(6,282
|
)
|
|
|
(77
|
)
|
Revisions to previous estimates
|
|
|
(13,121
|
)
|
|
|
(226
|
)
|
|
|
|
|
|
|
BalanceDecember 31, 2006
|
|
|
98,657
|
|
|
|
1,122
|
|
|
|
|
|
|
|
Proved developed reserves:
|
|
|
|
|
|
|
|
|
December 31, 2004
|
|
|
16,986
|
|
|
|
102
|
|
|
|
|
|
|
|
December 31, 2005
|
|
|
47,078
|
|
|
|
454
|
|
|
|
|
|
|
|
December 31, 2006
|
|
|
51,004
|
|
|
|
496
|
|
|
|
The standardized measure of discounted future net cash flows
relating to proved oil and natural gas reserves and the changes
in standardized measure of discounted future net cash flows
relating to proved oil and natural gas reserves were prepared in
accordance with the provisions of SFAS No. 69. Future
cash inflows were computed by applying prices at year end to
estimated future production. Future production and development
costs are computed by estimating the expenditures to be incurred
in developing and producing the proved oil and natural gas
F-21
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
reserves at year end, based on year-end costs and assuming
continuation of existing economic conditions.
Future income tax expenses are calculated by applying
appropriate year-end tax rates to future pretax net cash flows
relating to proved oil and natural gas reserves, less the tax
basis of properties involved.
Future income tax expenses give effect to permanent differences,
tax credits and loss carryforwards relating to the proved oil
and natural gas reserves. Future net cash flows are discounted
at a rate of 10% annually to derive the standardized measure of
discounted future net cash flows. This calculation procedure
does not necessarily result in an estimate of the fair market
value of Approachs oil and natural gas properties.
The standardized measure of discounted future net cash flows
relating to proved oil and natural gas reserves are as follows
(in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2004
|
|
|
2005
|
|
|
2006
|
|
|
|
|
Future cash flows
|
|
$
|
414,417
|
|
|
$
|
1,003,363
|
|
|
$
|
709,184
|
|
Future production costs
|
|
|
(81,441
|
)
|
|
|
(193,171
|
)
|
|
|
(198,023
|
)
|
Future development costs
|
|
|
(53,115
|
)
|
|
|
(101,152
|
)
|
|
|
(108,451
|
)
|
Future income tax expense
|
|
|
(94,316
|
)
|
|
|
(238,013
|
)
|
|
|
(109,784
|
)
|
|
|
|
|
|
|
Future net cash flows
|
|
|
185,545
|
|
|
|
471,027
|
|
|
|
292,926
|
|
10% annual discount for estimated
timing of cash flows
|
|
|
(125,267
|
)
|
|
|
(324,588
|
)
|
|
|
(215,049
|
)
|
|
|
|
|
|
|
Standardized measure of discounted
future net cash flows
|
|
$
|
60,278
|
|
|
$
|
146,439
|
|
|
$
|
77,877
|
|
|
|
Future cash flows as shown above were reported without
consideration for the effects of hedging transactions
outstanding at each period end. The effect of hedging
transactions on the future cash flows for the years ended
December 31, 2004, 2005, and 2006 was immaterial.
F-22
Approach
Resources Inc. and affiliated entities
Notes to combined financial
statements(continued)
The changes in the standardized measure of discounted future net
cash flows relating to proved oil and natural gas reserves are
as follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2004
|
|
|
2005
|
|
|
2006
|
|
|
|
|
Balance, beginning of period
|
|
$
|
|
|
|
$
|
60,278
|
|
|
$
|
146,439
|
|
Net change in sales and transfer
prices and in production (lifting) costs related to future
production
|
|
|
|
|
|
|
53,167
|
|
|
|
(106,246
|
)
|
Changes in estimated future
development costs
|
|
|
|
|
|
|
(87,109
|
)
|
|
|
(43,229
|
)
|
Sales and transfers of oil and gas
produced during the period
|
|
|
(5,503
|
)
|
|
|
(38,379
|
)
|
|
|
(40,852
|
)
|
Net change due to extensions,
discoveries and improved recovery
|
|
|
65,781
|
|
|
|
7,613
|
|
|
|
28,418
|
|
Net change due to purchase of
minerals in place
|
|
|
|
|
|
|
17,804
|
|
|
|
|
|
Net change due to revisions in
quantity estimates
|
|
|
|
|
|
|
116,125
|
|
|
|
(22,112
|
)
|
Previously estimated development
costs incurred during the period
|
|
|
|
|
|
|
53,116
|
|
|
|
52,108
|
|
Accretion of discount
|
|
|
|
|
|
|
16,686
|
|
|
|
15,546
|
|
Other
|
|
|
|
|
|
|
9,616
|
|
|
|
(4,498
|
)
|
Net changes in income taxes
|
|
|
|
|
|
|
(62,478
|
)
|
|
|
52,303
|
|
|
|
|
|
|
|
|
|
$
|
60,278
|
|
|
$
|
146,439
|
|
|
$
|
77,877
|
|
|
|
Average wellhead prices in effect at December 31, 2004,
2005 and 2006 inclusive of adjustments for quality and location
used in determining future net revenues related to the
standardized measure calculation are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
2004
|
|
2005
|
|
2006
|
|
|
Oil (per Bbl)
|
|
$
|
41.33
|
|
$
|
56.50
|
|
$
|
58.05
|
Natural gas liquids (per Bbl)
|
|
$
|
|
|
$
|
|
|
$
|
30.55
|
Gas (per Mcf)
|
|
$
|
6.93
|
|
$
|
9.20
|
|
$
|
6.55
|
|
|
*************
F-23
|
|
|
|
|
|
|
|
|
March 31,
2007
|
|
|
|
|
|
(unaudited)
|
|
|
ASSETS
|
CURRENT ASSETS:
|
|
|
|
|
Cash
|
|
$
|
5,374,312
|
|
Accounts receivable:
|
|
|
|
|
Joint interest owners
|
|
|
2,463,016
|
|
Oil and gas sales
|
|
|
3,460,716
|
|
Unrealized gain on commodity
derivatives
|
|
|
|
|
Prepaid expenses and other current
assets
|
|
|
851,984
|
|
|
|
|
|
|
Total current assets
|
|
|
12,150,028
|
|
PROPERTIES AND
EQUIPMENT:
|
|
|
|
|
Oil and gas properties, at cost,
using the successful efforts method of accounting
|
|
|
164,725,412
|
|
Furniture, fixtures and equipment
|
|
|
256,144
|
|
|
|
|
|
|
|
|
|
164,981,556
|
|
Less accumulated depreciation,
depletion and amortization
|
|
|
(26,859,117
|
)
|
|
|
|
|
|
Net properties and equipment
|
|
|
138,122,439
|
|
OTHER ASSETS
|
|
|
119,313
|
|
|
|
|
|
|
Total assets
|
|
$
|
150,391,780
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS
EQUITY
|
CURRENT LIABILITIES:
|
|
|
|
|
Accounts payable
|
|
$
|
5,064,424
|
|
Oil and gas payables
|
|
|
5,407,044
|
|
Accrued liabilities
|
|
|
970,819
|
|
Unrealized loss on commodity
derivatives
|
|
|
121,312
|
|
|
|
|
|
|
Total current liabilities
|
|
|
11,563,599
|
|
NON-CURRENT
LIABILITIES:
|
|
|
|
|
Long-term debt
|
|
|
52,169,000
|
|
Deferred income taxes
|
|
|
17,514,107
|
|
Asset retirement obligations
|
|
|
154,817
|
|
|
|
|
|
|
Total liabilities
|
|
|
81,401,523
|
|
COMMITMENTS AND CONTINGENCIES
STOCKHOLDERS EQUITY:
|
|
|
|
|
Preferred stock
|
|
|
|
|
Common stock
|
|
|
30,021
|
|
Additional paid-in capital
|
|
|
38,883,309
|
|
Retained earnings
|
|
|
30,076,927
|
|
Loans to stockholders
|
|
|
|
|
|
|
|
|
|
Total stockholders equity
|
|
|
68,990,257
|
|
|
|
|
|
|
Total liabilities and
stockholders equity
|
|
$
|
150,391,780
|
|
|
|
See accompanying notes to these
combined financial statements.
F-24
|
|
|
|
|
|
|
|
|
|
|
|
|
For the three
months ended March 31,
|
|
|
|
2006
|
|
|
2007
|
|
|
|
|
|
(unaudited)
|
|
|
(unaudited)
|
|
|
REVENUES:
|
|
|
|
|
|
|
|
|
Oil and gas sales
|
|
$
|
15,679,887
|
|
|
$
|
11,546,458
|
|
Overhead and services income
|
|
|
121,945
|
|
|
|
133,496
|
|
|
|
|
|
|
|
Total revenues
|
|
|
15,801,832
|
|
|
|
11,679,954
|
|
EXPENSES:
|
|
|
|
|
|
|
|
|
Lease operating expense
|
|
|
972,741
|
|
|
|
979,581
|
|
Severance and production taxes
|
|
|
380,105
|
|
|
|
375,140
|
|
Exploration
|
|
|
196,345
|
|
|
|
623,040
|
|
General and administrative
|
|
|
750,272
|
|
|
|
1,645,552
|
|
Depletion, depreciation and
amortization
|
|
|
3,280,592
|
|
|
|
3,090,726
|
|
|
|
|
|
|
|
Total expenses
|
|
|
5,580,055
|
|
|
|
6,714,039
|
|
|
|
|
|
|
|
OPERATING INCOME
(LOSS)
|
|
|
10,221,777
|
|
|
|
4,965,915
|
|
OTHER:
|
|
|
|
|
|
|
|
|
Interest income (expense), net
|
|
|
(725,067
|
)
|
|
|
(955,903
|
)
|
Change in fair value of commodity
derivatives
|
|
|
6,192,708
|
|
|
|
(4,626,308
|
)
|
|
|
|
|
|
|
INCOME (LOSS) BEFORE PROVISION
FOR INCOME TAXES
|
|
|
15,689,418
|
|
|
|
(616,296
|
)
|
PROVISION (BENEFIT) FOR INCOME
TAXES
|
|
|
5,280,326
|
|
|
|
(35,000
|
)
|
|
|
|
|
|
|
NET INCOME (LOSS)
|
|
$
|
10,409,092
|
|
|
$
|
(581,296
|
)
|
|
|
|
|
|
|
EARNINGS (LOSS) PER
SHARE:
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
3.49
|
|
|
$
|
(0.19
|
)
|
|
|
|
|
|
|
Diluted
|
|
$
|
3.39
|
|
|
$
|
(0.19
|
)
|
|
|
|
|
|
|
WEIGHTED AVERAGE SHARES
OUTSTANDING:
|
|
|
|
|
|
|
|
|
Basic
|
|
|
2,985,000
|
|
|
|
2,987,411
|
|
|
|
|
|
|
|
Diluted
|
|
|
3,069,945
|
|
|
|
2,987,411
|
|
|
|
See accompanying notes to these
combined financial statements.
F-25
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loans to
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Retained
|
|
|
stockholders
|
|
|
|
|
|
|
|
|
|
|
|
|
Additional
|
|
|
earnings
|
|
|
including
|
|
|
|
|
|
|
Common
stock
|
|
|
paid-in
|
|
|
(accumulated
|
|
|
accrued
|
|
|
|
|
|
|
Shares
|
|
|
Amount
|
|
|
capital
|
|
|
deficit)
|
|
|
interest
|
|
|
Total
|
|
|
|
|
BALANCE,
January 1, 2007
|
|
|
3,065,385
|
|
|
$
|
30,654
|
|
|
$
|
43,067,000
|
|
|
$
|
30,658,223
|
|
|
$
|
(4,184,324
|
)
|
|
$
|
69,571,553
|
|
Retirement of loans to stockholders
|
|
|
(84,550
|
)
|
|
|
(846
|
)
|
|
|
(4,183,478
|
)
|
|
|
|
|
|
|
4,184,324
|
|
|
|
|
|
Issuance of restricted stock
|
|
|
21,250
|
|
|
|
213
|
|
|
|
(213
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Net loss
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(581,296
|
)
|
|
|
|
|
|
|
(581,296
|
)
|
|
|
|
|
|
|
BALANCE,
March 31, 2007 (unaudited)
|
|
|
3,002,085
|
|
|
$
|
30,021
|
|
|
$
|
38,883,309
|
|
|
$
|
30,076,927
|
|
|
$
|
|
|
|
$
|
68,990,257
|
|
|
|
See accompanying notes to these
combined financial statements.
F-26
|
|
|
|
|
|
|
|
|
|
|
|
|
For the three
months ended March 31,
|
|
|
|
2006
|
|
|
2007
|
|
|
|
|
|
(unaudited)
|
|
|
(unaudited)
|
|
OPERATING ACTIVITIES:
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$
|
10,409,092
|
|
|
$
|
(581,296
|
)
|
Adjustments to reconcile net income
(loss) to net cash provided by operating activities:
|
|
|
|
|
|
|
|
|
Depletion, depreciation and
amortization
|
|
|
3,280,592
|
|
|
|
3,087,930
|
|
Amortization of loan origination
fees
|
|
|
12,763
|
|
|
|
23,830
|
|
Accretion of discount on asset
retirement obligations
|
|
|
|
|
|
|
2,796
|
|
Change in fair value of commodity
derivatives
|
|
|
(6,192,708
|
)
|
|
|
4,626,308
|
|
Exploration expense
|
|
|
196,345
|
|
|
|
623,040
|
|
Deferred income taxes
|
|
|
5,006,746
|
|
|
|
(35,000
|
)
|
Changes in operating assets and
liabilities:
|
|
|
|
|
|
|
|
|
Accounts receivable
|
|
|
1,913,515
|
|
|
|
2,346,655
|
|
Prepaid expenses and other current
assets
|
|
|
(239,321
|
)
|
|
|
(427,903
|
)
|
Accounts payable
|
|
|
945
|
|
|
|
(2,448,795
|
)
|
Oil and gas payables
|
|
|
(1,003,810
|
)
|
|
|
466,629
|
|
Accrued liabilities
|
|
|
(768,394
|
)
|
|
|
(1,996,961
|
)
|
|
|
|
|
|
|
Cash provided by operating
activities
|
|
|
12,615,765
|
|
|
|
5,687,233
|
|
INVESTING ACTIVITIES:
|
|
|
|
|
|
|
|
|
Additions to oil and gas properties
|
|
|
(24,585,618
|
)
|
|
|
(9,716,495
|
)
|
Additions to other property and
equipment, net
|
|
|
7,178
|
|
|
|
(693
|
)
|
|
|
|
|
|
|
Cash used in investing activities
|
|
|
(24,578,440
|
)
|
|
|
(9,717,188
|
)
|
FINANCING ACTIVITIES:
|
|
|
|
|
|
|
|
|
Borrowings under credit facility,
net
|
|
|
11,235,000
|
|
|
|
4,550,000
|
|
Purchase of common stock
|
|
|
(997,463
|
)
|
|
|
|
|
Stock option cancellation payment
|
|
|
(273,547
|
)
|
|
|
|
|
Income taxes on interest income
from loans to stockholders
|
|
|
(20,771
|
)
|
|
|
|
|
Loan origination fees
|
|
|
(25,000
|
)
|
|
|
(56,974
|
)
|
|
|
|
|
|
|
Cash provided by financing
activities
|
|
|
9,918,219
|
|
|
|
4,493,026
|
|
|
|
|
|
|
|
CHANGE IN CASH AND CASH
EQUIVALENTS
|
|
|
(2,044,456
|
)
|
|
|
463,071
|
|
CASH AND CASH
EQUIVALENTS
, beginning
of period
|
|
|
3,219,463
|
|
|
|
4,911,241
|
|
|
|
|
|
|
|
CASH AND CASH
EQUIVALENTS
, end of
period
|
|
$
|
1,175,007
|
|
|
$
|
5,374,312
|
|
|
|
|
|
|
|
SUPPLEMENTAL DISCLOSURE OF CASH
FLOW INFORMATION:
|
|
|
|
|
|
|
|
|
Cash paid for interest
|
|
$
|
552,943
|
|
|
$
|
1,273,057
|
|
|
|
|
|
|
|
Cash paid for income taxes
|
|
$
|
450,000
|
|
|
$
|
1,200,000
|
|
|
|
|
|
|
|
SUPPLEMENTAL DISCLOSURE OF
NON-CASH TRANSACTION:
|
|
|
|
|
|
|
|
|
Return of common shares in exchange
for retirement of loans to stockholders
|
|
$
|
|
|
|
$
|
4,184,324
|
|
|
|
See accompanying notes to these
combined financial statements.
F-27
|
|
1.
|
Summary of
significant accounting policies
|
Basis of
presentation and use of estimates
The interim combined financial statements of Approach Resources
Inc. are unaudited and contain all adjustments (consisting
primarily of normal recurring accruals) necessary for a fair
statement of the results for the interim periods presented.
Results for interim periods are not necessarily indicative of
results to be expected for a full year or for previously
reported periods due in part, but not limited to, the volatility
in prices for crude oil and natural gas, future commodity prices
for derivative hedging contracts, interest rates, estimates of
reserves, drilling risks, geological risks, transportation
restrictions, the timing of acquisitions, product demand, market
competition, and interruptions of production. You should read
these combined interim financial statements in conjunction with
the audited combined financial statements and notes thereto
included in this Prospectus beginning on
page F-2.
The accompanying combined financial statements have been
prepared in accordance with accounting principles generally
accepted in the United States of America (GAAP) and
include the accounts of Approach Resources Inc.
(ARI) and its wholly-owned subsidiaries and Approach
Oil & Gas Inc. (AOG) and its wholly-owned
subsidiaries. Collectively, ARI and AOG are referred to as
we, our, Approach or
the Company. Intercompany accounts and transactions
are eliminated. In preparing the accompanying financial
statements, management has made certain estimates and
assumptions that affect reported amounts in the financial
statements and disclosures of contingencies. Actual results may
differ from those estimates. Significant assumptions are
required in the valuation of proved oil and natural gas
reserves, which may affect the amount at which oil and natural
gas properties are recorded. It is at least reasonably possible
these estimates could be revised in the near term, and these
revisions could be material.
Earnings (loss)
per common share
In accordance with SFAS No. 128,
Earnings Per
Share
, we report basic earnings (loss) per common share,
which excludes the effect of potentially dilutive securities,
and diluted earnings (loss) per common share, which includes the
effect of all potentially dilutive securities unless their
impact is anti-dilutive. Stock options were the only dilutive
securities outstanding during the three months ended
March 31, 2007. During the three months ended
March 31, 2007, the effects of 21,250 non-vested restricted
shares granted on March 14, 2007 and options to acquire
115,385 common shares were excluded from diluted weighted
average shares outstanding because their effects would have been
anti-dilutive. The following is a reconciliation of basic and
diluted weighted average shares outstanding for the three months
ended March 31, 2006:
|
|
|
|
|
|
Weighted average shares
outstanding, basic
|
|
|
2,985,000
|
Dilutive effect of stock options
|
|
|
84,945
|
|
|
|
|
Weighted average shares
outstanding, diluted
|
|
|
3,069,945
|
|
|
F-28
Approach
Resources Inc. and affiliated entities
Notes to unaudited combined financial
statements(continued)
|
|
2.
|
Loans to
stockholders and stockholder notes payable
|
During each of the years ended December 31, 2003 and 2004,
in exchange for cash and notes receivable from employees and
entities owned by or affiliated with management, we issued
450,000 shares of common stock. The notes had an outstanding
principal balance of $3,613,850 at December 31, 2006. In
January 2007, the remaining notes and accrued interest of
$570,474 were retired in exchange for 84,550 shares of
common stock held by management. The notes provided for interest
at 6 percent and were payable upon the earlier of
December 31, 2008, the registration of the underlying
common stock, or upon a merger with another entity or upon a
divestiture of our assets. The notes were collateralized by the
underlying common stock purchased.
We have a revolving loan agreement with Frost Bank (the
Agreement), which provides a borrowing base
determined by the bank based on oil and gas reserve values. As
of December 31, 2006, the borrowing base was $60,000,000.
Borrowings outstanding under the Agreement at December 31,
2006 and March 31, 2007 were $47,619,000 and $52,169,000,
respectively. In February 2007, the line of credit was raised to
$100,000,000 and the borrowing base was increased to
$75,000,000. In June 2007, the maturity date of the Agreement
was extended to July 2010. The borrowings bear interest based on
the banks prime rate or the LIBOR. The interest rate
applicable to our outstanding borrowings was approximately 8.25%
as of December 31, 2006 and 7.02% as of March 31,
2007. Principal payments are not required until the final
maturity date of the agreement, at which time any outstanding
loan balances shall be due and payable in full. In addition, the
Agreement requires payment of a quarterly fee equal to
three-eights of one percent (0.375%) of the unused portion of
the borrowing base. The borrowings are collateralized by
substantially all of our oil and gas properties. The Agreement
contains various covenants, the most restrictive of which
requires us to maintain a modified current ratio of at least
one. We were in compliance with the covenants at
December 31, 2006 and March 31, 2007.
We also have outstanding unused letters of credit under the
Agreement totaling $400,000, which reduce amounts available for
borrowing under the Agreement.
|
|
4.
|
Stock based
compensation
|
Restricted stock
grants
On March 14, 2007, we granted 21,250 restricted shares to
an employee. Such shares had a grant-date fair value of $49.49
per share, and vest in three equal incrementsone third on
the earlier of the closing date of an initial public offering of
Approach common stock, or February 21, 2008 (the
Initial Vesting Date), and one-third on each of the
two following anniversaries of the Initial Vesting Date. As of
March 31, 2007, all of the restricted shares were unvested.
F-29
Approach
Resources Inc. and affiliated entities
Notes to unaudited combined financial
statements(continued)
Total income tax expense (benefit) differed from the amounts
computed by applying the U.S. Federal statutory tax rates
and estimated state rates to pre-tax income for the three months
ended March 31, 2006 and 2007 due primarily to adjustments
to the valuation allowance applied to net operating loss
carryovers of AOG. AOG provided a valuation allowance related to
its deferred tax assets resulting primarily from net operating
loss carryforwards based upon managements inability to
assess the amount to be realized until completion of the merger
with ARI.
In 2005, we entered into three natural gas swap agreements. The
first two swaps were for 170,000 MMBtu per month and
expired in September 2005. The other swap was for an average of
282,000 MMBtu per month through December 2006. In January
2006, we entered into a natural gas swap for approximately
257,000 MMBtu per month that expired in December 2006. In
June 2006, we entered into a natural gas swap for
100,000 MMBtu per month for the fourth quarter of 2006 and
an average of 250,000 MMBtu per month for 2007. In May
2007, we entered into a natural gas collar for 2008 based on the
NYMEX floating price with a $7.50 floor and a $11.45 ceiling. In
addition, we entered into a WAHA basis swap for 2008 for $0.69
per mcf. Both of these hedges were for an average volume of
approximately 186,000 MMBtu per month. Our oil and gas
sales revenues include realized gains of $1,424,277 and
$2,155,140 from the swaps for the three months ended
March 31, 2006 and 2007, respectively. The estimated
unrealized gain or loss from the swaps amounted to a gain of
$6,192,708 and a loss of $4,626,308 at March 31, 2006 and
2007, respectively. Changes in unrealized gains and losses are
reflected in other income (expense) on our statements of
operations. The net unrealized gain and loss is reflected as a
current asset and liability, respectively, based on the
associated production months. The fair value of commodity
derivatives were estimated based on the present value of the
difference in exchange-quoted forward price curves and
contractual settlement prices multiplied by notional quantities.
We are exposed to credit loss in the event of nonperformance by
the counterparty on our oil and gas swaps. However, we do not
anticipate nonperformance by the counterparty over the term of
the swaps.
|
|
7.
|
Commitments and
contingencies
|
Employment
agreements
We have employment agreements with our officers and selected
other employees. These agreements are automatically renewed for
successive terms of one year unless employment is terminated at
the end of the term by written notice given to the employee not
less than 60 days prior to the end of such term. Our
maximum commitment under the employment agreements, which would
apply if the employees covered by these agreements were all
terminated without cause, is approximately $1,500,000 at
March 31, 2007.
F-30
Approach
Resources Inc. and affiliated entities
Notes to unaudited combined financial
statements(continued)
Operating
leases
In April 2007, we signed a five-year lease for approximately
13,000 square feet of office space in Fort Worth,
Texas. That lease calls for minimum monthly rent payments of
approximately $20,000 from August 2007 through October 2012.
Litigation
We are involved in various claims and legal actions arising in
the normal course of business. In our opinion, the resolution of
these matters is not expected to have a material adverse effect
on our financial position or results of operations.
Equity
financing
On June 25, 2007, Yorktown Energy Partners VII, L.P. and
Lubar Equity Fund, LLC loaned an aggregate of $20,000,000 to
Approach Oil & Gas Inc. under two convertible
promissory notes of $10,000,000 each. These notes bear interest
at a rate of 7.00% per annum and mature on June 25, 2010.
These notes are convertible at the election of the lender into
shares of equity securities of Approach Oil & Gas Inc.
upon the occurrence of certain events and automatically, and
without further action required by any person, convert into
shares of our common stock upon the consummation of this
offering. The number of shares of our common stock to be issued
upon the automatic conversion of these notes will be equal to
the quotient obtained by dividing (a) the outstanding
principal and accrued interest on each respective note by
(b) the initial public offering price per share, less any
underwriting discount per share for the shares of our common
stock that are issued in this offering. The shares of our common
stock issued to Yorktown Energy Partners VII, L.P. and Lubar
Equity Fund, LLC upon such automatic conversion will be entitled
to the same registration rights as those provided to certain
holders of our common stock in connection with the contribution
agreement. The total principal and interest owned under these
notes as of June 30, 2007 was $20,023,014, consisting of
$10,011,507 owed to each of Yorktown Energy Partners VII, L.P.
and Lubar Equity Fund, LLC. Yorktown Energy Partners VII, L.P.
is an affiliate of the Yorktown entities, and Lubar Equity Fund,
LLC is an affiliate of Sheldon B. Lubar, who serves as a member
of our board of directors.
Canadian
unconventional gas investment
In May 2007, we acquired shares of common stock of a
Canadian-based
private exploration company focused on tight gas and shale gas
opportunities in Canada. Our investment amounted to
approximately $917,000 and is a
non-controlling
interest.
*************
F-31
Report of
independent registered public accounting firm
Board of Directors
Approach Resources Inc.
Fort Worth, Texas
We have audited the accompanying Historical Summaries of
Revenues and Direct Operating Expenses of Properties to be
Acquired by Approach Resources Inc., for the years ended
December 31, 2005 and 2006 (Historical
Summaries). The Historical Summaries are the
responsibility of the management of Approach Resources Inc. Our
responsibility is to express an opinion on the Historical
Summaries based on our audit.
We conducted our audit in accordance with the standards of the
Public Company Accounting Oversight Board (United States). Those
standards require that we plan and perform the audit to obtain
reasonable assurance about whether the Historical Summaries are
free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in
the Historical Summaries. An audit also includes assessing the
accounting principles used and significant estimates made by
management, as well as evaluating the overall Historical
Summaries presentation. We believe that our audit provides a
reasonable basis for our opinion.
The accompanying Historical Summaries were prepared for the
purpose of complying with the rules and regulations of the
Securities and Exchange Commission as described in Note 1
and are not intended to be a complete presentation of the
properties revenues and expenses.
In our opinion, the Historical Summaries referred to above
present fairly, in all material respects, the revenues and
direct operating expenses of the properties to be acquired by
Approach Resources Inc. in conformity with accounting principles
generally accepted in the United States of America.
May 7, 2007
Dallas, Texas
F-32
Statements of
revenue and direct operating expenses of properties to be
acquired by Approach Resources Inc.
for the years ended December 31, 2005 and 2006 and the three
months ended March 31, 2006 and 2007 (unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three months
ended
|
|
|
Year ended
December 31,
|
|
March
31,
|
|
|
2005
|
|
2006
|
|
2006
|
|
2007
|
|
|
|
|
|
|
|
(unaudited)
|
|
(unaudited)
|
|
Crude oil and natural gas sales
|
|
$
|
19,371,892
|
|
$
|
19,558,497
|
|
$
|
5,936,955
|
|
$
|
3,801,767
|
Direct operating expenses
|
|
|
2,484,364
|
|
|
2,584,567
|
|
|
729,895
|
|
|
587,286
|
|
|
|
|
|
|
Net revenue
|
|
$
|
16,887,528
|
|
$
|
16,973,930
|
|
$
|
5,207,060
|
|
$
|
3,214,481
|
|
|
See notes to Historical
Summaries.
F-33
Notes to
historical summaries of revenue and direct
operating expenses of properties to be acquired by Approach
Resources Inc.
for the years ended December 31, 2005 and 2006 and the three
months ended March 31, 2006 and 2007 (unaudited)
1. Basis
of preparation
The accompanying statements of revenue and direct operating
expenses relate to the operations of certain crude oil and
natural gas properties in the Ozona Northeast field located in
Texas that are to be acquired by Approach Resources Inc.
(Approach) to be completed upon the effectiveness of
Approach completing its initial public offering. The acquired
properties are referred to herein as the Neo Canyon Acquisition
Properties.
Approach is the operator of the properties prior to the
acquisition of the additional interest. The accompanying
statements of revenues and direct operating expenses were
derived from the historical accounting records of Approach and
reflect the acquired interest in the revenues and direct
operating expenses of the Neo Canyon Acquisition Properties.
Such amounts may not be representative of future operations. The
statements do not include depreciation, depletion and
amortization, general and administrative expenses, income taxes
or interest expense as these costs may not be comparable to the
expenses to be incurred by Approach on a prospective basis.
Revenue is recognized when crude oil and natural gas quantities
are delivered to or collected by the respective purchaser. Title
to the produced quantities transfers to the purchaser at the
time the purchaser collects or receives the quantities. Prices
for such production are defined in sales contracts and are
readily determinable based on certain publicly available
indices. All transportation costs are accounted for as a
reduction of crude oil and natural gas sales revenue.
As of December 31, 2005 and 2006, crude oil production was
sold to one independent purchaser and natural gas production was
sold to one affiliated purchaser.
Direct operating expenses are recorded when the related
liability is incurred. Direct operating expenses include lease
operating expenses and production taxes.
The process of preparing financial statements in conformity with
generally accepted accounting principles requires the use of
estimates and assumptions regarding certain types of revenues
and expenses. Such estimates primarily relate to unsettled
transactions and events as of the date of the financial
statements. Accordingly, upon settlement, actual results may
differ from estimated amounts.
Historical financial statements reflecting financial position,
results of operations and cash flows required by generally
accepted accounting principles are not presented as such
information is not meaningful to the Neo Canyon Acquisition
Properties. Accordingly, the historical summaries of revenue and
direct operating expenses are presented in lieu of the financial
statements required under
Rule 3-05
of the Securities and Exchange Commission
Regulation S-X.
F-34
Notes to
historical summaries of revenue and direct
operating expenses of properties to be acquired by Approach
Resources Inc.
for the years ended December 31, 2005 and 2006 and the three
months ended March 31, 2006 and 2007
(unaudited)(continued)
Interim financial
information
In the opinion of Approachs management, the information
furnished herein reflects all adjustments, consisting of only
normal recurring adjustments, necessary for a fair presentation
of the results of the interim periods reported herein. Operating
results for the three months ended March 31, 2007 may
not necessarily be indicative of the results for the year ending
December 31, 2007.
2. Related
party transactions
The properties were operated by Approach Resources Inc. during
the three months ended March 31, 2006 and 2007 and the
years ended December 31, 2005 and 2006. During those
periods, Approach Resources Inc. charged the properties overhead
amounting to approximately $69,224, $100,467 $168,514 and
$338,991, respectively. Such overhead charges are included in
direct operating expenses.
3. Supplemental
information on oil and gas reserves (unaudited)
All of the operations of the Neo Canyon Acquisition Properties
are directly related to crude oil and natural gas producing
activities located in West Texas. The Neo Canyon Acquisition
Properties proved crude oil and natural gas reserves have
been estimated by independent petroleum engineers. Proved
reserves are the estimated quantities that geologic and
engineering data demonstrate with reasonable certainty to be
recoverable in future years from known reservoirs under existing
economic and operating conditions. Proved developed reserves are
the quantities expected to be recovered through existing wells
with existing equipment and operating methods. Due to the
inherent uncertainties and the limited nature of reservoir data,
such estimates are subject to change as additional information
becomes available. The reserves actually recovered and the
timing of production of these reserves may be substantially
different from the original estimate. Revisions result primarily
from new information obtained from development drilling and
production history; acquisitions of oil and gas properties; and
changes
F-35
Notes to
historical summaries of revenue and direct
operating expenses of properties to be acquired by Approach
Resources Inc.
for the years ended December 31, 2005 and 2006 and the three
months ended March 31, 2006 and 2007
(unaudited)(continued)
in economic factors. The Neo Canyon Acquisition Properties
proved reserves are summarized in the table below.
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural gas
|
|
|
Oil
|
|
|
|
(MMcf)
|
|
|
(MBbl)
|
|
|
|
|
Reserves at January 1, 2005
|
|
|
24,727
|
|
|
|
151
|
|
Extensions and discoveries
|
|
|
1,181
|
|
|
|
11
|
|
Revisions to previous estimates
|
|
|
19,073
|
|
|
|
330
|
|
Production
|
|
|
(2,082
|
)
|
|
|
(25
|
)
|
|
|
|
|
|
|
Reserves at December 31, 2005
|
|
|
42,899
|
|
|
|
467
|
|
Extensions and discoveries
|
|
|
6,421
|
|
|
|
61
|
|
Revisions to previous estimates
|
|
|
(5,526
|
)
|
|
|
(105
|
)
|
Production
|
|
|
(2,645
|
)
|
|
|
(32
|
)
|
|
|
|
|
|
|
Reserves at December 31, 2006
|
|
|
41,149
|
|
|
|
391
|
|
|
|
|
|
|
|
Proved developed reserves
|
|
|
|
|
|
|
|
|
December 31, 2005
|
|
|
19,595
|
|
|
|
198
|
|
December 31, 2006
|
|
|
21,400
|
|
|
|
170
|
|
|
|
Standardized
measure
The standardized measure of discounted future net cash flows
(standardized measure) and changes in such cash
flows are prepared using assumptions required by the Financial
Accounting Standards Board. Such assumptions include the use of
year-end prices for crude oil and natural gas and year-end costs
for estimated future development and production expenditures to
produce year-end estimated proved reserves. Discounted future
net cash flows are calculated using a 10% discount rate.
The standardized measure does not represent managements
estimate of our future cash flows or the value of proved crude
oil and natural gas reserves. Probable and possible reserves,
which may become proved in the future, are excluded from the
calculations. Furthermore, year-end prices used to determine the
standardized measure of discounted cash flows, are influenced by
seasonal demand and other factors and may not be the most
representative in estimating future revenues or reserve data.
Price and cost revisions are primarily the net result of changes
in year-end prices, based on beginning of year reserve
estimates. Quantity estimate revisions are primarily the result
of
F-36
Notes to
historical summaries of revenue and direct
operating expenses of properties to be acquired by Approach
Resources Inc.
for the years ended December 31, 2005 and 2006 and the three
months ended March 31, 2006 and 2007
(unaudited)(continued)
higher prices resulting in extended economic lives of proved
reserves and significant amounts of proved undeveloped reserves
becoming economic, as well as increased development activities.
The standardized measure of discounted future net cash flows
related to proved crude oil and natural gas reserves at
December 31, 2005 and 2006 is as follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
2005
|
|
|
2006
|
|
|
|
|
Future cash inflows
|
|
$
|
420,581
|
|
|
$
|
292,399
|
|
Future production
|
|
|
(76,357
|
)
|
|
|
(81,784
|
)
|
Future development costs
|
|
|
(42,895
|
)
|
|
|
(45,957
|
)
|
Future income taxes
|
|
|
|
|
|
|
(1,647
|
)
|
|
|
|
|
|
|
Future net cash flows
|
|
|
301,329
|
|
|
|
163,011
|
|
10% annual discount
|
|
|
(192,251
|
)
|
|
|
(112,306
|
)
|
|
|
|
|
|
|
Standardized measure of discounted
future net cash flows
|
|
$
|
109,078
|
|
|
$
|
50,705
|
|
|
|
The primary changes in the standardized measure of discounted
future net cash flows for the twelve months ended
December 31, 2005 and 2006 are as follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
2005
|
|
|
2006
|
|
|
|
|
Balance at beginning of year
|
|
$
|
43,139
|
|
|
$
|
109,078
|
|
Net changes in prices and
production costs
|
|
|
16,646
|
|
|
|
(56,734
|
)
|
Net changes due to extensions,
discoveries and improved recovery
|
|
|
3,402
|
|
|
|
10,265
|
|
Net changes in future development
costs
|
|
|
(33,524
|
)
|
|
|
(9,707
|
)
|
Sales of oil and gas produced, net
|
|
|
(16,888
|
)
|
|
|
(16,974
|
)
|
Revisions of previous quantity
estimates
|
|
|
57,406
|
|
|
|
(9,314
|
)
|
Net change in income taxes
|
|
|
|
|
|
|
(726
|
)
|
Previously estimated development
costs incurred
|
|
|
22,764
|
|
|
|
22,332
|
|
Accretion of discount
|
|
|
5,453
|
|
|
|
6,136
|
|
Other
|
|
|
10,680
|
|
|
|
(3,651
|
)
|
|
|
|
|
|
|
Balance at end of year
|
|
$
|
109,078
|
|
|
$
|
50,705
|
|
|
|
F-37
shares
Common stock
Prospectus
|
|
Book running
manager
|
Joint lead
manager
|
,
2007
Until ,
2007 (25 days after the date of this prospectus), all
dealers that effect transactions in our common stock, whether or
not participating in this offering, may be required to deliver a
prospectus. This requirement is in addition to a dealers
obligation to deliver a prospectus when acting as an underwriter
and with respect to unsold allotments or subscriptions.
Part II
Information not required in prospectus
|
|
Item 13.
|
Other expenses
of issuance and distribution
|
The following table sets forth estimates of all expenses payable
by the registrant in connection with the sale of common stock
being registered. The selling stockholder will not bear any
portion of such expenses. With the exception of SEC registration
fee, the NASD filing fee and the NASDAQ Global Market
application and entry listing fee, the amounts set forth below
are estimates.
|
|
|
|
|
|
SEC registration fee
|
|
$
|
4,061
|
NASD filing fee
|
|
|
13,725
|
NASDAQ Global Market application
and entry listing fee
|
|
|
100,000
|
Accounting fees and expenses
|
|
|
*
|
Legal fees and expenses
|
|
|
*
|
Printing and engraving
|
|
|
*
|
Advisory fee
|
|
|
*
|
Miscellaneous fees and expenses
|
|
|
*
|
|
|
|
|
Total
|
|
$
|
*
|
|
|
|
|
|
*
|
|
To be completed by amendment.
|
|
|
Item 14.
|
Indemnification
of directors and officers
|
Our restated certificate of incorporation provides that no
director or officer will be liable to the corporation or any of
its stockholders for damages for breach of fiduciary duty as a
director or officer occurring on or after the date of
incorporation; provided, however, that the foregoing provision
shall not eliminate or limit the liability of a director or
officer (i) for any breach of the directors duty of
loyalty to the corporation or its stockholders, (ii) for
acts or omissions not in good faith or which involved
intentional misconduct, fraud or a knowing violation of the law,
(iii) the payment of dividends in violation of
Section 174 of the General Corporation Law of the State of
Delaware or (iv) for any transaction from which the
director derived an improper personal benefit. In addition, if
the General Corporation Law of the State of Delaware is amended
to authorize corporate action further eliminating or limiting
the personal liability of directors, then the liability of a
director of the corporation shall be eliminated or limited to
the fullest extent permitted by the General Corporation Law of
the State of Delaware, as so amended. Our restated bylaws
provide that the corporation will indemnify, and advance
expenses to, any officer or director to the fullest extent
authorized by the General Corporation Law of the State of
Delaware.
Section 145 of the General Corporation Law of the State of
Delaware provides that a corporation may indemnify directors and
officers as well as other employees and individuals against
expenses, including attorneys fees, judgments, fines and
amounts paid in settlement in connection with specified actions,
suits and proceedings whether civil, criminal, administrative or
investigative, other than a derivative action by or in the right
of the corporation, if they acted
II-1
in good faith and in a manner they reasonably believed to be in
or not opposed to the best interests of the corporation and,
with respect to any criminal action or proceeding, had no
reasonable cause to believe their conduct was unlawful. A
similar standard is applicable in the case of derivative
actions, except that indemnification extends only to expenses,
including attorneys fees, incurred in connection with the
defense or settlement of such action and the statute requires
court approval before there can be any indemnification where the
person seeking indemnification has been found liable to the
corporation. The statute provides that it is not exclusive of
other indemnification that may be granted by a
corporations charter, bylaws, disinterested director vote,
stockholder vote, agreement or otherwise.
Our restated certificate of incorporation also contains
indemnification rights for our directors and our officers.
Specifically, our restated certificate of incorporation provides
that we shall indemnify our officers and directors to the
fullest extent authorized by the General Corporation Law of the
State of Delaware. Further, we may maintain insurance on behalf
of our officers and directors against expenses, liability or
loss asserted incurred by them in their capacities as officers
and directors.
We will obtain directors and officers insurance to
cover our directors, officers and some of our employees for
certain liabilities.
We will enter into written indemnification agreements with our
directors and executive officers. Under these agreements, if an
officer or director makes a claim of indemnification to us,
either a majority of the independent directors or independent
legal counsel selected by the independent directors must review
the relevant facts and make a determination whether the officer
or director has met the standards of conduct under Delaware law
that would permit (under Delaware law) and require (under the
indemnification agreement) us to indemnify the officer or
director.
The registration rights agreement we entered into in connection
with our earlier financings provide for the indemnification by
the investors in those financings of our officers and directors
for certain liabilities.
|
|
Item 15.
|
Recent sales
of unregistered securities
|
In the three years preceding the filing of this registration
statement, we have issued and sold the following securities that
were not registered under the Securities Act:
1. On August 16, 2004, we issued 1,130,000 shares
of our common stock to Yorktown Energy Partners V, L.P. and
certain of our employees in consideration of $11,300,000,
$1,202,500 of which was evidenced by full recourse promissory
notes secured by pledge of the securities purchased. These
shares were issued in a transaction exempt from the registration
requirements of the Securities Act under Section 4(2) of
the Securities Act.
2. On August 30, 2004, we issued 125,000 shares
of our common stock to certain of our employees in consideration
of $1,250,000 evidenced by full recourse promissory notes
secured by pledge of the securities purchased. These shares were
issued in a transaction exempt from the registration
requirements of the Securities Act under Section 4(2) of
the Securities Act.
3. On March 14, 2007, we issued 21,250 shares of
restricted common stock to one of our executive officers. These
shares were issued in a transaction exempt from the registration
requirements of the Securities Act pursuant to Rule 701,
promulgated under the Securities Act.
II-2
4. On June 25, 2007, Approach Oil & Gas Inc.
issued convertible promissory notes to each of Yorktown Energy
Partners VII, L.P. and Lubar Equity Fund, LLC in the
aggregate amount of $20,000,000. The notes are convertible into
shares of equity securities of Approach Oil & Gas Inc.
at the election of the individual lender upon the occurrence of
certain events and are automatically convertible into shares of
our common stock upon the consummation of the offering described
in the prospectus contained within this registration statement.
The number of shares of our common stock to be issued upon the
automatic conversion of these notes will be equal to the
quotient obtained by dividing (a) the outstanding principal
and accrued interest on each respective note by (b) the
initial public offering price per share, less any underwriting
discount per share for the shares of our common stock that are
issued in this offering. These notes were issued in a
transaction exempt from the registration requirements of the
Securities Act under Section 4(2) of the Securities Act.
|
|
Item 16.
|
Exhibits and
financial statement schedules
|
|
|
|
|
|
|
Exhibit
|
|
|
number
|
|
Description
|
|
|
|
1
|
.1*
|
|
Form of Underwriting Agreement.
|
|
3
|
.1
|
|
Form of Restated Certificate of
Incorporation of Approach Resources Inc.
|
|
3
|
.2
|
|
Form of Restated Bylaws of
Approach Resources Inc.
|
|
4
|
.1*
|
|
Specimen Common Stock Certificate.
|
|
5
|
.1*
|
|
Opinion of Thompson &
Knight LLP regarding legality of securities issued
|
|
10
|
.1*
|
|
Form of Indemnity Agreement
between Approach Resources Inc. and each of its directors and
officers.
|
|
10
|
.2
|
|
Contribution Agreement by and
among Approach Resources Inc. and the equity holders identified
therein, dated June 29, 2007.
|
|
10
|
.3
|
|
Employment Agreement by and
between Approach Resources Inc. and J. Ross Craft dated
January 1, 2003.
|
|
10
|
.4
|
|
Employment Agreement by and
between Approach Resources Inc. and Steven P. Smart dated
January 1, 2003.
|
|
10
|
.5
|
|
Employment Agreement by and
between Approach Resources Inc. and Glenn W. Reed dated
January 1, 2003.
|
|
10
|
.6
|
|
Approach Resources Inc. 2007 Stock
Incentive Plan, effective as of June 28, 2007.
|
|
10
|
.7
|
|
Convertible Promissory Note issued
by Approach Oil & Gas Inc. to Yorktown Energy Partners
VII, L.P. dated June 25, 2007.
|
|
10
|
.8
|
|
Convertible Promissory Note issued
by Approach Oil & Gas Inc. to Lubar Equity Fund, LLC
dated June 25, 2007.
|
|
10
|
.9
|
|
$100,000,000 Revolving Amended and
Restated Credit Agreement by and among Approach
Resources I, LP, as borrower, The Frost National Bank, as
administrative agent and lender, and the financial institutions
party thereto, dated February 15, 2007.
|
|
10
|
.10
|
|
Amendment to Amended and Restated
Credit Agreement dated as of February 15, 2007 between
Approach Resources I, LP, The Frost National Bank, as
administrative agent, and the lenders party thereto, dated
June 14, 2007.
|
|
10
|
.11*
|
|
Form of Business Opportunities
Agreement
dated ,
2007, among Approach Resources Inc. and the other signatories
thereto.
|
|
10
|
.12
|
|
Form of Option Agreement under
2003 Stock Option Plan.
|
II-3
|
|
|
|
|
|
Exhibit
|
|
|
number
|
|
Description
|
|
|
|
10
|
.13
|
|
Restricted Stock Award Agreement
by and between Approach Resources Inc. and J. Curtis Henderson
dated March 14, 2007.
|
|
10
|
.14*
|
|
Form of Summary of Stock Option
Grant under Approach Resources Inc. 2007 Stock Incentive
Plan.
|
|
10
|
.15*
|
|
Form of Stock Award Agreement
under Approach Resources Inc. 2007 Stock Incentive Plan.
|
|
21
|
.1
|
|
List of Subsidiaries.
|
|
23
|
.1
|
|
Consent of Hein &
Associates LLP.
|
|
23
|
.2
|
|
Consent of DeGolyer &
MacNaughton.
|
|
23
|
.3
|
|
Consent of Cawley,
Gillespie & Associates, Inc.
|
|
23
|
.4*
|
|
Consent of Thompson &
Knight LLP (contained in Exhibit 5.1).
|
|
24
|
|
|
Power of Attorney (contained on
the signature page hereto).
|
|
|
|
|
|
*
|
|
To be filed by amendment.
|
The undersigned registrant hereby undertakes:
(a) Insofar as indemnification for liabilities arising
under the Securities Act of 1933, as amended, may be permitted
to directors, officers and controlling persons of the registrant
pursuant to the provisions described in Item 14 or
otherwise, the registrant has been advised that in the opinion
of the Securities and Exchange Commission, such indemnification
is against public policy as expressed in the Act and is,
therefore, unenforceable. In the event that a claim for
indemnification against such liabilities (other than the payment
by the registrant of expenses incurred or paid by a director,
officer or controlling person of the registrant in the
successful defense of any action, suit or proceeding) is
asserted by such director, officer or controlling person in
connection with the securities being registered, the registrant
will, unless in the opinion of its counsel the matter has been
settled by controlling precedent, submit to a court of
appropriate jurisdiction the question of whether such
indemnification by it is against public policy as expressed in
the Act and will be governed by the final adjudication of such
issue.
(b) To provide the underwriter(s) at the closing specified
in the underwriting agreements certificates in such
denominations and registered in such names as required by the
underwriter to permit prompt delivery to each purchaser.
(c) For purposes of determining any liability under the
Securities Act of 1933, the information omitted from the form of
prospectus filed as part of this registration statement in
reliance upon Rule 430A and contained in a form of
prospectus filed by the registrant pursuant to
Rule 424(b)(1) or (4) or 497(h) under the Securities
Act shall be deemed to be part of this registration statement as
of the time it was declared effective.
(d) For the purpose of determining any liability under the
Securities Act of 1933, each post-effective amendment that
contains a form of prospectus shall be deemed to be a new
registration statement relating to the securities offering
therein, and the offering of such securities at that time shall
be deemed to be the initial bona fide offering thereof.
II-4
Signatures
Pursuant to the requirements of the Securities Act of 1933, as
amended, the Registrant has duly caused this registration
statement to be signed on its behalf by the undersigned,
thereunto duly authorized, in the City of Fort Worth, and
State of Texas, on the
12
th
day of July, 2007.
APPROACH RESOURCES INC.
J. Ross Craft
President and Chief Executive Officer
Pursuant to the requirements of the Securities Act of 1933, as
amended, this registration statement has been signed by the
following persons in the capacities indicated on July 12,
2007. Each person whose signature appears below constitutes and
appoints J. Ross Craft and Steven P. Smart, and each of them
individually, his true and lawful attorneys-in-fact and agents,
with full power of substitution and resubstitution, for him and
in his name, place and stead, in any and all capacities, to sign
any and all amendments (including post-effective amendments) to
this registration statement under the Securities Act of 1933, as
amended, and to file the same, with all exhibits thereto and
other documents in connection therewith, with the SEC, granting
unto said attorneys-in-fact and agents, and each of them, full
power and authority to do and perform each and every act and
thing requisite and necessary to be done in connection
therewith, as fully to all intents and purposes as he might or
could do in person, hereby ratifying and confirming all that
said attorneys-in-fact and agents or any of them, or their or
his substitute or substitutes, may lawfully do or cause to be
done by virtue hereof. This document may be executed by the
signatories hereto on any number of counterparts, all of which
constitute one and the same instrument.
|
|
|
|
|
Signature
|
|
Title
|
|
/s/
J.
Ross Craft
J.
Ross Craft
|
|
President, Chief Executive Officer
and Director
(Principal Executive Officer)
|
|
|
|
/s/
Steven
P. Smart
Steven
P. Smart
|
|
Executive Vice President and Chief
Financial Officer
(Principal Financial and Accounting Officer)
|
|
|
|
/s/
Bryan
H. Lawrence
Bryan
H. Lawrence
|
|
Director and Chairman of the Board
of Directors
|
|
|
|
/s/
James
H. Brandi
James
H. Brandi
|
|
Director
|
|
|
|
/s/
James
C. Crain
James
C. Crain
|
|
Director
|
|
|
|
/s/
Sheldon
B. Lubar
Sheldon
B. Lubar
|
|
Director
|
|
|
|
/s/
Christopher
J. Whyte
Christopher
J. Whyte
|
|
Director
|
II-5
Exhibit
index
|
|
|
|
|
|
Exhibit
|
|
|
Number
|
|
Description
|
|
|
|
1
|
.1*
|
|
Form of Underwriting Agreement.
|
|
3
|
.1
|
|
Form of Restated Certificate of
Incorporation of Approach Resources Inc.
|
|
3
|
.2
|
|
Form of Restated Bylaws of
Approach Resources Inc.
|
|
4
|
.1*
|
|
Specimen Common Stock Certificate.
|
|
5
|
.1*
|
|
Opinion of Thompson &
Knight LLP regarding legality of securities issued.
|
|
10
|
.1*
|
|
Form of Indemnity Agreement
between Approach Resources Inc. and each of its directors and
officers.
|
|
10
|
.2
|
|
Contribution Agreement by and
among Approach Resources Inc. and the equity holders identified
therein, dated June 29, 2007.
|
|
10
|
.3
|
|
Employment Agreement by and
between Approach Resources Inc. and J. Ross Craft dated
January 1, 2003.
|
|
10
|
.4
|
|
Employment Agreement by and
between Approach Resources Inc. and Steven P. Smart dated
January 1, 2003.
|
|
10
|
.5
|
|
Employment Agreement by and
between Approach Resources Inc. and Glenn W. Reed dated
January 1, 2003.
|
|
10
|
.6
|
|
Approach Resources Inc. 2007 Stock
Incentive Plan, effective as of June 28, 2007.
|
|
10
|
.7
|
|
Convertible Promissory Note issued
by Approach Oil & Gas Inc. to Yorktown Energy Partners
VII, L.P. dated June 25, 2007.
|
|
10
|
.8
|
|
Convertible Promissory Note issued
by Approach Oil & Gas Inc. to Lubar Equity Fund, LLC
dated June 25, 2007.
|
|
10
|
.9
|
|
$100,000,000 Revolving Amended and
Restated Credit Agreement by and among Approach
Resources I, LP, as borrower, The Frost National Bank, as
administrative agent and lender, and the financial institutions
party thereto, dated February 15, 2007.
|
|
10
|
.10
|
|
Amendment to Amended and Restated
Credit Agreement dated as of February 15, 2007 between
Approach Resources I, LP, The Frost National Bank, as
administrative agent, and the lenders party thereto, dated
June 14, 2007.
|
|
10
|
.11*
|
|
Form of Business Opportunities
Agreement
dated ,
2007, among Approach Resources Inc. and the other signatories
thereto.
|
|
10
|
.12
|
|
Form of Option Agreement under
2003 Stock Option Plan.
|
|
10
|
.13
|
|
Restricted Stock Award Agreement
by and between Approach Resources Inc. and J. Curtis Henderson
dated March 14, 2007.
|
|
10
|
.14*
|
|
Form of Summary of Stock Option
Grant under Approach Resources Inc. 2007 Stock Incentive Plan.
|
|
10
|
.15*
|
|
Form of Stock Award Agreement
under Approach Resources Inc. 2007 Stock Incentive Plan.
|
|
21
|
.1
|
|
List of Subsidiaries.
|
|
23
|
.1
|
|
Consent of Hein &
Associates LLP.
|
|
23
|
.2
|
|
Consent of DeGolyer &
MacNaughton.
|
|
23
|
.3
|
|
Consent of Cawley,
Gillespie & Associates, Inc.
|
|
23
|
.4*
|
|
Consent of Thompson &
Knight LLP (contained in Exhibit 5.1).
|
|
24
|
|
|
Power of Attorney (contained on
the signature page hereto).
|
|
|
|
|
|
*
|
|
To be filed by amendment.
|
II-6
Exhibit 10.2
CONTRIBUTION AGREEMENT
by and among
APPROACH RESOURCES INC.,
THE STOCKHOLDERS OF
APPROACH OIL & GAS INC.,
APPROACH OIL & GAS INC.,
LUBAR EQUITY FUND, LLC,
YORKTOWN ENERGY PARTNERS VII, L.P.
and
NEO CANYON EXPLORATION, L.P.
and joined in by
THE GENERAL PARTNER OF NEO CANYON EXPLORATION, L.P.
June 29, 2007
TABLE OF CONTENTS
|
|
|
|
|
|
|
Page
|
ARTICLE I. DEFINITIONS
|
|
|
1
|
|
|
|
|
|
|
ARTICLE II. CONTRIBUTION TRANSACTION
|
|
|
9
|
|
2.1 Contribution of AOG Common Stock to ARI
|
|
|
9
|
|
2.2 Contribution of Neo Canyon Assets to ARI
|
|
|
9
|
|
2.3 Contribution of Lubar Note to ARI
|
|
|
9
|
|
2.4 Contribution of Yorktown Note to ARI
|
|
|
9
|
|
2.5 Issuance of New Certificates
|
|
|
9
|
|
2.6 Certificate Legends
|
|
|
9
|
|
2.7 Fractional Shares
|
|
|
10
|
|
2.8 Certain Adjustments
|
|
|
10
|
|
2.9 Proration of Costs and Revenues
|
|
|
10
|
|
2.10 Receipts Not Reflected
|
|
|
10
|
|
2.11 Expenses Not Reflected
|
|
|
11
|
|
2.12 Transfer Taxes
|
|
|
11
|
|
|
|
|
|
|
ARTICLE III. CLOSING
|
|
|
11
|
|
3.1 Time and Place
|
|
|
11
|
|
3.2 Deliveries at Closing
|
|
|
12
|
|
|
|
|
|
|
ARTICLE IV. REPRESENTATIONS AND WARRANTIES OF AOG
|
|
|
12
|
|
4.1 Organization and Power
|
|
|
12
|
|
4.2 Authorizations; Execution and Validity
|
|
|
12
|
|
4.3 Capitalization
|
|
|
12
|
|
4.4 Financial Statements; Other Financial Data
|
|
|
13
|
|
4.5 Consents
|
|
|
13
|
|
4.6 No Defaults or Conflicts
|
|
|
14
|
|
4.7 Agreements, Contracts and Commitments
|
|
|
14
|
|
4.8 Litigation
|
|
|
14
|
|
4.9 ERISA Compliance; Labor
|
|
|
14
|
|
4.10 Taxes
|
|
|
15
|
|
4.11 Brokers
|
|
|
16
|
|
4.12 Absence of Certain Changes or Events
|
|
|
16
|
|
4.13 Compliance with Laws
|
|
|
16
|
|
4.14 Transactions with Related Parties
|
|
|
16
|
|
4.15 Agents
|
|
|
17
|
|
4.16 Books and Records
|
|
|
17
|
|
4.17 Information Furnished
|
|
|
17
|
|
4.18 Directors and Officers
|
|
|
17
|
|
4.19 Bank Accounts
|
|
|
17
|
|
4.20 Owned Real Property
|
|
|
17
|
|
i
TABLE OF CONTENTS
|
|
|
|
|
|
|
Page
|
4.21 Leased Real Property
|
|
|
17
|
|
4.22 Insurance
|
|
|
18
|
|
4.23 Title to Oil and Gas Properties
|
|
|
18
|
|
4.24 Environmental Matters
|
|
|
18
|
|
4.25 Patents, Trademarks and Similar Rights
|
|
|
20
|
|
|
|
|
|
|
ARTICLE V. REPRESENTATIONS AND WARRANTIES OF NEO CANYON
|
|
|
20
|
|
5.1 Organization and Power
|
|
|
20
|
|
5.2 Authorization; Execution and Validity
|
|
|
20
|
|
5.3 Consents
|
|
|
20
|
|
5.4 No Defaults or Conflicts
|
|
|
21
|
|
5.5 Brokers
|
|
|
21
|
|
5.6 Litigation
|
|
|
21
|
|
5.7 Title to the Neo Canyon Oil and Gas Properties
|
|
|
21
|
|
5.8 Environmental Matters
|
|
|
21
|
|
5.9 Taxes and Assessments
|
|
|
22
|
|
5.10 Outstanding Capital Commitments
|
|
|
23
|
|
5.11 Compliance with Laws
|
|
|
23
|
|
5.12 Forward Sales
|
|
|
23
|
|
5.13 Properties
|
|
|
23
|
|
5.14 Consents and Preferential Purchase Rights
|
|
|
23
|
|
5.15 Contracts
|
|
|
23
|
|
5.16 Intentionally Omitted
|
|
|
23
|
|
5.17 Intentionally Omitted
|
|
|
24
|
|
5.18 Intellectual Property
|
|
|
24
|
|
5.19 Accredited Investor
|
|
|
24
|
|
5.20 Restricted Securities
|
|
|
24
|
|
5.21 Investment Intent
|
|
|
24
|
|
|
|
|
|
|
ARTICLE VI. REPRESENTATIONS AND WARRANTIES OF THE AOG STOCKHOLDERS,
LUBAR AND YORKTOWN VII
|
|
|
24
|
|
6.1 Organization and Good Standing
|
|
|
24
|
|
6.2 Authority and Enforceability
|
|
|
25
|
|
6.3 No Conflict; Required Filings and Consents
|
|
|
25
|
|
6.4 Ownership
|
|
|
25
|
|
6.5 Accredited Investor
|
|
|
25
|
|
6.6 Restricted Securities
|
|
|
25
|
|
6.7 Investment Intent
|
|
|
26
|
|
|
|
|
|
|
ARTICLE VII. REPRESENTATIONS AND WARRANTIES OF ARI
|
|
|
26
|
|
7.1 Organization and Power
|
|
|
26
|
|
7.2 Authorizations; Execution and Validity
|
|
|
26
|
|
7.3 Capitalization
|
|
|
27
|
|
7.4 Financial Statements; Other Financial Data
|
|
|
28
|
|
ii
TABLE OF CONTENTS
|
|
|
|
|
|
|
Page
|
7.5 Consents
|
|
|
28
|
|
7.6 No Defaults or Conflicts
|
|
|
28
|
|
7.7 Agreements, Contracts and Commitments
|
|
|
28
|
|
7.8 Litigation
|
|
|
29
|
|
7.9 ERISA Compliance; Labor
|
|
|
29
|
|
7.10 Taxes
|
|
|
29
|
|
7.11 Brokers
|
|
|
30
|
|
7.12 Absence of Certain Changes or Events
|
|
|
30
|
|
7.13 Compliance with Laws
|
|
|
30
|
|
7.14 Transactions with Related Parties
|
|
|
31
|
|
7.15 Agents
|
|
|
31
|
|
7.16 Books and Records
|
|
|
31
|
|
7.17 Information Furnished
|
|
|
31
|
|
7.18 Directors and Officers
|
|
|
32
|
|
7.19 Bank Accounts
|
|
|
32
|
|
7.20 Owned Real Property
|
|
|
32
|
|
7.21 Leased Real Property
|
|
|
32
|
|
7.22 Insurance
|
|
|
32
|
|
7.23 Title to Oil and Gas Properties
|
|
|
33
|
|
7.24 Environmental Matters
|
|
|
33
|
|
7.25 Patents, Trademarks and Similar Rights
|
|
|
34
|
|
7.26 Plugging and Abandonment
|
|
|
34
|
|
7.27 Additional Drilling Obligations
|
|
|
34
|
|
7.28 Gas Imbalances
|
|
|
34
|
|
|
|
|
|
|
ARTICLE VIII. COVENANTS
|
|
|
34
|
|
8.1 Ordinary Course of Business
|
|
|
34
|
|
8.2 AOG Restricted Activities and Transactions
|
|
|
35
|
|
8.3 Neo Canyon Restricted Activities and Transactions
|
|
|
36
|
|
8.4 HSR and Other Regulatory Matters
|
|
|
37
|
|
8.5 Commercially Reasonable Efforts
|
|
|
37
|
|
8.6 New ARI Charter
|
|
|
38
|
|
8.7 Officers and Directors
|
|
|
38
|
|
8.8 Access to Information
|
|
|
38
|
|
8.9 Section 351
|
|
|
38
|
|
8.10 ARI Registration Statement
|
|
|
38
|
|
8.11 Blue Sky
|
|
|
39
|
|
8.12 Notification Of Certain Matters
|
|
|
39
|
|
8.13 Consents and Preferential Rights
|
|
|
39
|
|
8.14 Assumption and Indemnification
|
|
|
39
|
|
8.15 Indemnification Procedures
|
|
|
41
|
|
8.16 Limits on Indemnification
|
|
|
42
|
|
8.17 Further Assurances
|
|
|
42
|
|
8.18 Over-allotment Option
|
|
|
42
|
|
iii
TABLE OF CONTENTS
|
|
|
|
|
|
|
Page
|
ARTICLE IX. CONDITIONS
|
|
|
42
|
|
9.1 Conditions to Obligations of Each Party
|
|
|
42
|
|
9.2 Conditions to Obligations of Neo Canyon
|
|
|
43
|
|
9.3 Conditions to Obligations of ARI
|
|
|
44
|
|
9.4 Conditions to Obligations of AOG
|
|
|
45
|
|
9.5 Conditions to Obligations of each of the AOG Stockholders, Lubar and Yorktown VII
|
|
|
46
|
|
|
|
|
|
|
ARTICLE X. TERMINATION
|
|
|
47
|
|
10.1 Termination
|
|
|
47
|
|
10.2 Effect of Termination
|
|
|
47
|
|
10.3 Fees and Expenses
|
|
|
47
|
|
|
|
|
|
|
ARTICLE XI. MISCELLANEOUS
|
|
|
48
|
|
11.1 Waiver And Amendment
|
|
|
48
|
|
11.2 Nonsurvival of Representations and Warranties
|
|
|
48
|
|
11.3 Assignment
|
|
|
48
|
|
11.4 Notices
|
|
|
48
|
|
11.5 Governing Law
|
|
|
49
|
|
11.6 Severability
|
|
|
49
|
|
11.7 Counterparts
|
|
|
49
|
|
11.8 Headings
|
|
|
49
|
|
11.9 Enforcement Of The Contribution Agreement
|
|
|
50
|
|
11.10 Entire Agreement; Third Party Beneficiaries
|
|
|
50
|
|
11.11 Certain Assignments
|
|
|
50
|
|
11.12 Representation
|
|
|
50
|
|
11.13 Joinder
|
|
|
50
|
|
iv
EXHIBITS
|
|
|
|
|
Exhibit A
|
|
|
|
AOG Oil and Gas Properties Leases and Wells
|
Exhibit B
|
|
|
|
ARI Oil and Gas Properties Leases and Wells
|
Exhibit C
|
|
|
|
Neo Canyon Oil and Gas Properties Leases and Wells
|
Exhibit D
|
|
|
|
Form of Conveyance
|
Exhibit E
|
|
|
|
Registration Rights Agreement
|
DISCLOSURE SCHEDULES
|
|
|
|
|
Schedule 4.3(b)
|
|
|
|
AOG Subsidiaries
|
Schedule 4.3(c)
|
|
|
|
AOG Stockholders Agreements and Voting Trusts
|
Schedule 4.4
|
|
|
|
AOG Financial Statements
|
Schedule 4.5
|
|
|
|
AOG Consents
|
Schedule 4.7
|
|
|
|
AOG Material Contracts
|
Schedule 4.8
|
|
|
|
AOG Legal Proceedings
|
Schedule 4.9
|
|
|
|
AOG Employee Benefit Plans
|
Schedule 4.10
|
|
|
|
AOG Taxes
|
Schedule 4.12
|
|
|
|
Absence of Certain Changes (AOG)
|
Schedule 4.14
|
|
|
|
AOG Related Parties
|
Schedule 4.15
|
|
|
|
AOG Agents
|
Schedule 4.18
|
|
|
|
AOG Directors and Officers
|
Schedule 4.19
|
|
|
|
AOG Bank Accounts
|
Schedule 4.21
|
|
|
|
AOG Real Property Leases
|
Schedule 4.22
|
|
|
|
AOG Insurance
|
Schedule 4.23
|
|
|
|
Title to AOG Oil and Gas Properties
|
Schedule 4.24
|
|
|
|
AOG Environmental Matters
|
Schedule 4.25
|
|
|
|
AOG Intellectual Property
|
Schedule 5.3
|
|
|
|
Neo Canyon Consents
|
Schedule 5.6
|
|
|
|
Neo Canyon Legal Proceedings
|
Schedule 5.7
|
|
|
|
Title to Neo Canyon Oil and Gas Properties
|
Schedule 5.8
|
|
|
|
Neo Canyon Environmental Matters
|
Schedule 5.10
|
|
|
|
Neo Canyon Capital Commitments
|
Schedule 5.12
|
|
|
|
Neo Canyon Forward Sales
|
Schedule 5.13
|
|
|
|
Neo Canyon Oil and Gas Properties Subject to Sales Contract
|
Schedule 5.14
|
|
|
|
Neo Canyon Leases Subject to Consents or Preferential Purchase Rights
|
Schedule 5.15
|
|
|
|
Neo Canyon Contracts
|
Schedule 5.18
|
|
|
|
Neo Canyon Intellectual Property
|
Schedule 7.3(a)
|
|
|
|
ARI Capitalization
|
Schedule 7.3(b)
|
|
|
|
ARI Subsidiaries
|
Schedule 7.3(c)
|
|
|
|
ARI Stockholders Agreements and Voting Trusts
|
Schedule 7.4
|
|
|
|
ARI Financial Statements
|
Schedule 7.5
|
|
|
|
ARI Consents
|
Schedule 7.7
|
|
|
|
ARI Material Contracts
|
Schedule 7.8
|
|
|
|
ARI Legal Proceedings
|
v
|
|
|
|
|
Schedule 7.9
|
|
|
|
ARI Employee Benefit Plans
|
Schedule 7.10
|
|
|
|
ARI Taxes
|
Schedule 7.12
|
|
|
|
ARI Financial Statements
|
Schedule 7.14
|
|
|
|
ARI Related Parties
|
Schedule 7.15
|
|
|
|
ARI Agents
|
Schedule 7.18
|
|
|
|
ARI Directors and Officers
|
Schedule 7.19
|
|
|
|
ARI Bank Accounts
|
Schedule 7.21
|
|
|
|
ARI Real Property Leases
|
Schedule 7.22
|
|
|
|
ARI Insurance
|
Schedule 7.23
|
|
|
|
Title to ARI Oil and Gas Properties
|
Schedule 7.24
|
|
|
|
ARI Environmental Matters
|
Schedule 7.25
|
|
|
|
ARI Intellectual Property
|
Schedule 7.27
|
|
|
|
ARI Additional Drilling Obligations
|
Schedule 7.28
|
|
|
|
ARI Gas Imbalances
|
Schedule 8.2
|
|
|
|
Restricted Activities
|
vi
Execution version
CONTRIBUTION AGREEMENT
THIS CONTRIBUTION AGREEMENT, dated as of June 29, 2007 (this
Contribution Agreement
), is by
and among Approach Resources Inc., a Delaware corporation (
ARI
), Approach Oil & Gas Inc., a
Delaware corporation (
AOG
), all of the stockholders of AOG listed on the signature pages hereto
(the
AOG Stockholders
), Lubar Equity Fund, LLC, a Wisconsin limited liability company (
Lubar
),
Yorktown Energy Partners VII, L.P., a Delaware limited partnership (
Yorktown VII
), and Neo Canyon
Exploration, L.P., a Texas limited partnership (
Neo Canyon
), and is joined in by J. Cleo Thompson
Petroleum Management, L.L.C., a Texas limited liability company and the general partner of Neo
Canyon (
Neo Canyon GP
).
W I T N
E S S E T H:
WHEREAS, the AOG Stockholders currently own all of the outstanding common stock of AOG and
have agreed to transfer to ARI all of the outstanding capital stock of AOG owned by them in
exchange for shares of ARI Common Stock;
WHEREAS, Neo Canyon currently owns certain oil and gas properties in the Ozona Northeast Field
located in Crockett and Schleicher Counties, Texas and has agreed to transfer to ARI all of its
interest in such oil and gas properties in exchange for shares of ARI Common Stock on the terms and
subject to the conditions set forth in this Agreement;
WHEREAS, the parties intend for the foregoing transfers to qualify under Section 351(a) of the
Internal Revenue Code of 1986, as amended (the
Code
); and
WHEREAS, the transactions contemplated by this Contribution Agreement shall be effective upon
the consummation of the ARI Initial Public Offering.
NOW, THEREFORE, in consideration of the mutual covenants, representations, warranties and
agreements herein contained, the parties hereto agree as follows:
ARTICLE I.
DEFINITIONS
The terms set forth below in this
Article I
shall have the meanings ascribed to them
below or in the part of this Contribution Agreement referred to below:
Acquisition Proposal
means (i) any proposal for a merger, consolidation or other business
combination involving ARI or AOG, (ii) any proposal or offer to acquire in any manner a substantial
equity interest in ARI or AOG, (iii) any proposal or offer to acquire in any manner a substantial
portion of the ARI Oil and Gas Properties or the AOG Oil and Gas Properties, (iv) any proposal or
offer with respect to any recapitalization or restructuring (whether of equity or debt or a
combination thereof) with respect to ARI or AOG, or (v) any proposal or offer with respect to any
other transaction similar to any of the foregoing with respect to ARI or AOG.
AFEs
shall have the meaning set forth in
Section 5.10
hereto.
Affiliate
shall have the meaning ascribed to such term in Rule 12b-2 of the general rules
and regulations under the Securities Exchange Act of 1934, as in effect on the date of this
Contribution Agreement.
Aggregated Group
has the meaning set forth in
Section 4.9(a)
hereto.
AOG
has the meaning set forth in the introductory paragraph hereto.
AOG Audited Financial Statements
has the meaning set forth in
Section 4.4
hereto.
AOG Board
means the board of directors of AOG.
AOG Common Stock
means the common stock of AOG, par value $0.01 per share.
AOG Financial Statements
has the meaning set forth in
Section 4.4
hereto.
AOG Oil and Gas Properties
means all Oil and Gas Properties of AOG or any of its
Subsidiaries. Attached hereto as
Exhibit A
is a description of each Lease belonging to
AOG, or in which AOG has an interest, which
Exhibit A
shall be a part of the definition of
AOG Oil and Gas Properties. The respective net revenue interest and working interest of AOG
or any of its Subsidiaries in the AOG Oil and Gas Properties described on
Exhibit A
shall
be a part of the definition of AOG Oil and Gas Properties.
AOG Preferred Stock
means the preferred stock of AOG, par value $0.01 per share.
AOG Stockholders
has the meaning set forth in the introductory paragraph hereto.
AOG Unaudited Balance Sheet
has the meaning set forth in
Section 4.4
hereto.
ARI
has the meaning set forth in the introductory paragraph hereto.
ARI Audited Financial Statements
has the meaning set forth in
Section 7.4
hereto.
ARI Board
means the board of directors of ARI.
ARI Bylaws
means the bylaws of ARI, dated as of September 12, 2002, as amended.
ARI Common Stock
means the common stock of ARI, par value $0.01 per share, which par value
is subject to adjustment in connection with the ARI Initial Public Offering.
ARI Financial Statements
has the meaning set forth in
Section 7.4
hereto.
ARI Initial Public Offering
means the initial public offering of the ARI Common Stock
contemplated by the ARI Registration Statement.
ARI Material Adverse Effect
means a Material Adverse Effect on ARI, AOG and Neo Canyon,
taken as a whole.
2
ARI Oil and Gas Properties
means all Oil and Gas Properties of ARI or any of its
Subsidiaries. Attached hereto as
Exhibit B
is a description of each Lease and Well
belonging to ARI, or in which ARI has an interest, which
Exhibit B
shall be a part of the
definition of ARI Oil and Gas Properties. The respective net revenue interest and working
interest of ARI or any of its Subsidiaries in the ARI Oil and Gas Properties described on
Exhibit B
shall be a part of the definition of ARI Oil and Gas Properties.
ARI Preferred Stock
means the preferred stock of ARI, par value $0.01 per share.
ARI Registration Statement
means the Registration Statement on Form S-1 relating to the ARI
Common Stock to be filed with the Commission by ARI in accordance with
Section 8.9
, and any
amendments thereto.
ARI Stockholders
means the holders of all of the outstanding shares of capital stock of ARI
as of the date hereof.
ARI Unaudited Financial Statements
has the meaning set forth in
Section 7.4
hereto.
ARIs Senior Lender
means Frost National Bank, N.A.
Basket Amount
shall have the meaning set forth in
Section 8.16
.
Business Day
means any day other than a Saturday, a Sunday or any other day when banks are
not open for business generally in the State of New York.
CERCLA
means the Comprehensive Environmental Response, Compensation and Liability Act, as
amended.
CERCLIS
means the Comprehensive Environmental Response, Compensation and Liability
Information System List.
Closing
has the meaning set forth in
Section 3.1
hereto.
Closing Date
has the meaning set forth in
Section 3.1
hereto.
Code
has the meaning set forth in the recitals hereto.
Contribution Agreement
has the meaning set forth in the introductory paragraph hereto.
Commission
means the U.S. Securities and Exchange Commission.
Conveyance
shall mean a Conveyance to effect the sale, transfer and conveyance of the Neo
Canyon Oil and Gas Properties, substantially in the form set forth in
Exhibit D
.
Defensible Title
means with, respect to the Oil and Gas Properties, such title and ownership
by ARI, AOG or Neo Canyon, as applicable, that:
3
(a) Except as set forth on
Schedules 4.23
,
5.7
and
7.23
,
respectively entitles ARI, AOG or Neo Canyon, as applicable, to receive and retain, without
reduction, suspension or termination, not less than the percentage set forth in
Exhibits
A
,
B
or
C
, respectively, as the net revenue interest of all
Hydrocarbons produced, saved and marketed from each Lease comprising such Oil and Gas
Property as set forth in
Exhibits A
,
B
or
C
, respectively, through
plugging, abandonment and salvage of all wells comprising or included in such Oil and Gas
Property, and except for changes or adjustments that result from the establishment of units,
changes in existing units (or the participating areas therein), or the entry into of pooling
or unitization agreements after the date hereof;
(b) obligates ARI, AOG or Neo Canyon, as applicable, to bear not greater than the
percentage set forth in
Exhibits A
,
B
or
C
, respectively, as the
working interest of the costs and expenses relating to the maintenance, development and
operation of each Lease comprising such Oil and Gas Property (including the plugging and
abandonment and site restoration with respect to all existing and future wells located
thereon or attributable thereto), through plugging, abandonment and salvage of all wells
comprising or included in such Oil and Gas Property, and except for changes or adjustments
that result from the establishment of units, changes in existing units (or the participating
areas therein), or the entry into of pooling or unitization agreements after the date
hereof;
(c) is free and clear of all Liens, except Permitted Liens;
(d) reflects that all royalties, rentals, Pugh clause payments, shut-in gas payments
and other payments due with respect to such Oil and Gas Property have been properly and
timely paid, except for payments held in suspense for title or other reasons which are
customary in the industry and which will not result in grounds for cancellation of the
Companys rights in such Oil and Gas Property as such suspense payments are set forth on
Schedules 4.23
,
5.7
and
7.23
, respectively; and
(e) reflects that all consents to assignment, notices of assignment or preferential
purchase rights which are applicable to or must be complied with in connection with the
transaction contemplated by this Agreement, or any prior sale, assignment or the transfer of
such Oil and Gas Property as such rights are set forth on
Schedule 5.7
, have been
obtained and complied with to the extent the failure to obtain or comply with the same could
have an ARI Material Adverse Effect;
provided, that: (i) the legal proceedings, if any, scheduled on
Schedule 4.8
,
Schedule 5.6
and
Schedule 7.8
shall not be considered to effect a reduction in the
value of the assets, and (ii) no fact, circumstance or condition of the title to an Oil and Gas
Property shall be considered to effect a reduction in the value of the assets, unless such fact,
circumstance or condition is of the type that can generally be expected to be encountered in the
area involved and is usually and customarily acceptable to reasonable and prudent operators,
interest owners and purchasers engaged in the business of the ownership, development and operation
of Oil and Gas Properties.
Effective Time
means the date and time of the closing under the Underwriting Agreement.
4
Employee Benefit Plan
means any employee benefit plan within the meaning of Section 3(3)
of ERISA and any bonus, deferred compensation, incentive compensation, stock ownership, stock
purchase, stock option, phantom stock, vacation, severance, disability, death benefit,
hospitalization or insurance plan providing benefits to any present or former employee or
contractor of the Company or any member of the Aggregated Group maintained by any such entity.
Environmental Law
means any Law of any Governmental Authority whose purpose is to conserve
or protect human health, the environment, wildlife or natural resources, including: the Clean Air
Act, as amended, the Federal Water Pollution Control Act, as amended, the Rivers and Harbors Act of
1899, as amended, the Safe Drinking Water Act, as amended, CERCLA, the Superfund Amendments and
Reauthorization Act of 1986, as amended, the Resource Conservation and Recovery Act of 1976, as
amended, the Hazardous and Solid Waste Amendments Act of 1984, as amended, the Toxic Substances
Control Act, as amended, the Occupational Safety and Health Act, as amended, the Hazardous
Materials Transportation Act, as amended, and any other federal, state and local law.
Governmental Authorities
means the federal, state, county, city and political subdivisions
in which any property of ARI, AOG or Neo Canyon, respectively, is located or which exercises
jurisdiction over any such property or entity, and any agency, department, commission, board,
bureau or instrumentality of any of them which exercises jurisdiction over any such property or
entity.
Hazardous Material
means (i) any hazardous substance, as defined by CERCLA; (ii) any
hazardous waste or solid waste, in either case as defined by the Resource Conservation and
Recovery Act of 1976, as amended; (iii) any solid, hazardous, dangerous or toxic chemical,
material, waste or substance, within the meaning of and regulated by any Environmental Law; (iv)
any asbestos containing materials in any form or condition; (v) any polychlorinated biphenyls in
any form or condition; (vi) petroleum, petroleum hydrocarbons, or any fraction or byproducts
thereof; or (vii) any air pollutant which is so designated by the United States Environmental
Protection Agency as authorized by the Clean Air Act, as amended.
Hedging Transaction
means any futures, hedge, swap, collar, put, call, floor, cap, option or
other contract that is intended to benefit from, relate to or reduce or eliminate the risk of
fluctuations in the price of commodities, including Hydrocarbons, interest rates, currencies or
securities.
HSR Act
means the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended.
Hydrocarbons
means oil, condensate, gas, casinghead gas and other liquid or gaseous
hydrocarbons.
Indemnified Party
shall have the meaning set forth in
Section 8.15
.
Indemnifying Party
shall have the meaning set forth in
Section 8.15
.
Intellectual Property
means (a) patent rights, (b) trademark rights, and (c) copyrights.
5
Knowledge
means actual knowledge of any officer or director of such party and, in the case
of Neo Canyon, the actual knowledge of any officer or manager of Neo Canyon GP.
Law
means any federal, state, local or foreign law, statute, rule, ordinance, code or
regulation.
Legal Proceedings
means any judicial, administrative or arbitral action, suit, proceeding
(public or private), litigation, investigation, complaint, claim or governmental proceeding.
Lien
means a lien, mortgage, deed of trust, pledge, hypothecation, assignment, deposit
arrangement, easement, preference, priority, assessment, security interest, lease, sublease,
charge, claim, adverse claim, levy, interest of other Persons or other encumbrance of any kind.
Lubar
has the meaning set forth in the introductory paragraph hereto.
Lubar Note
means that certain Convertible Promissory Note dated June 25, 2007 in the
principal amount of $10,000,000 payable by AOG to Lubar.
Material Adverse Effect
means a material adverse effect on the business, operations,
prospects, properties (including intangible properties), assets, operating results or condition
(financial or otherwise) liabilities or reserves of such Person; provided, however, that a general
deterioration in the economy or changes in oil and gas prices or other changes affecting the oil
and gas industry generally shall not be deemed to be a Material Adverse Effect.
Material Contracts
means all leases, contracts, agreements and instruments to which such
Person is a party as of the date hereof involving payment by or to such Person of more than
$1,000,000 and extending for a term of more than six months from the date of this Contribution
Agreement and not terminable without payment or penalty upon less than sixty (60) days notice.
Neo Canyon
has the meaning set forth in the introductory paragraph hereto.
Neo Canyon GP
has the meaning set forth in the introductory paragraph hereto.
Neo Canyon Oil and Gas Properties
means all Oil and Gas Properties of Neo Canyon, except as
specifically excluded on
Exhibit C
. Attached hereto as
Exhibit C
is a description
of each Lease and Well belonging to Neo Canyon, or in which Neo Canyon has an interest, which
Exhibit C
shall be a part of the definition of Neo Canyon Oil and Gas Properties. The
respective net revenue interest and working interest of Neo Canyon or any of its Subsidiaries
in the Neo Canyon Oil and Gas Properties described on
Exhibit C
shall be a part of the
definition of Neo Canyon Oil and Gas Properties.
New ARI Bylaws
shall mean the Amended and Restated Bylaws of ARI in such form as shall be
approved by the ARI Board prior to the Closing.
New ARI Charter
shall mean the Amended and Restated Certificate of Incorporation of ARI in
such form as shall be approved by the ARI Board and the ARI Stockholders prior to
6
the Closing and which shall authorize a sufficient number of ARI Common Stock as shall be
necessary to cover the shares of ARI Common Stock issuable pursuant to
Article II
.
Oil and Gas Properties
means all right, title, interest and estate, real or personal,
recorded or unrecorded, movable or immovable, tangible or intangible, in and to: (i) oil and gas
leases, oil, gas and mineral leases, subleases and other leaseholds, royalties, overriding
royalties, net profit interests, mineral fee interests, carried interests and other properties and
interests (the Leases) and the lands covered thereby (Land(s)) and any and all oil, gas, water
or injection wells thereon or applicable thereto (the Wells); (ii) any pools or units which
include all or a part of any Land or include any Well (the Units) and including, without
limitation, all right, title and interest in production from any such Unit, whether such Unit
production comes from wells located on or off of the Lands, and all tenements, hereditaments and
appurtenances belonging to, used or useful in connection with the Leases, Lands and Units; (iii)
interests under or derived from all contracts, agreements and instruments applicable to or by which
such properties are bound or created, to the extent applicable to such properties, including,
without limitation, operating agreements, gathering agreements, marketing agreements (including
commodity swap, collar and/or similar derivative agreements), transportation agreements, processing
agreements, seismic, geological and geophysical agreements, unitization, pooling and
communitization agreements, declarations and orders, joint venture agreements, and farmin and
farmout agreements; (iv) easements, permits, licenses, servitudes, rights-of-way, surface leases
and other surface rights appurtenant to, and used or held for use to the extent applicable to such
properties; (v) equipment, machinery, fixtures and other tangible personal property and
improvements located on or used or obtained in connection with such properties and (vi) seismic and
interpretive data applicable to such properties.
Order
means any order, judgment, injunction, ruling, writ, award, decree, statute, Law,
ordinance, rule or regulation.
Over-allotment Option
shall have the meaning set forth in
Section 8.18
.
Permit
means any permit, license, certificate (including a certificate of occupancy)
registration, authorization, application, filing, notice, qualification, waiver of any of the
foregoing or approval of a Governmental Authority.
Permitted Liens
means Liens (including mechanics, workers, repairers, materialmens,
warehousemens, landlords and other similar Liens) arising in the ordinary course of business as
would not individually or in the aggregate materially adversely affect the value of, or materially
adversely interfere with the use of, the property subject to them.
Person
means an individual, corporation, partnership (limited or general), limited liability
company, trust, joint stock company, Governmental Authority, unincorporated association or other
legal entity.
Property Costs
means all operating and production expenses of the Oil and Gas Properties
(including, without limitation, costs of insurance and ad valorem, property, severance, production
and similar Taxes based upon or measured by the ownership or operation of the Oil and Gas
Properties or the production of Hydrocarbons therefrom, but excluding any other
7
Taxes), capital expenditures incurred in the ownership and operation of the Oil and Gas
Properties in the ordinary course of business (including, without limitation, cash advances or cash
call amounts paid under applicable operating agreements), and overhead costs charged to the Oil and
Gas Properties under the applicable operating agreement or if none, charged to the Oil and Gas
Properties on the same basis as charged on the date of this Contribution Agreement.
Proscribed Action
shall have the meaning set forth in
Section 8.9
.
Real Property Leases
has the meaning set forth in
Section 4.21
hereto.
Registration Rights Agreement
means the registration rights agreement providing for the
registration under the Securities Act of the shares of ARI Common Stock to be received by the ARI
Stockholders, the AOG Stockholders, Lubar, Yorktown VII and Neo Canyon pursuant to this
Contribution Agreement in the form attached hereto as
Exhibit E
.
Securities Act
means the Securities Act of 1933, as amended.
Stockholders Agreement
means that certain Voting and Stockholders Agreement, dated as of
January 1, 2003, by and among ARI and each of the ARI Stockholders.
Subsidiary
or
Subsidiaries
means, with respect to any Person, each entity as to which such
Person (either alone or through or together with any other Subsidiary) (i) owns beneficially or of
record or has the power to vote or control, 50% or more of the voting securities of such entity or
of any class of equity interests of such entity the holders of which are ordinarily entitled to
vote for the election of the members of the board of directors or other persons performing similar
functions, (ii) in the case of partnerships, serves as a general partner, (iii) in the case of a
limited liability company, serves as a managing member or owns a majority of the equity interests
or (iv) otherwise has the ability to elect a majority of the directors, trustees or managing
members thereof.
Tax
or
Taxes
means all income, profits, franchise, gross receipts, capital, sales, use,
withholding, value added, ad valorem, transfer, employment, social security, disability,
occupation, asset, property, severance, documentary, stamp, excise and other taxes, duties and
similar governmental charges or assessments imposed by or on behalf of any Governmental Authority
and any interest, fines, penalties or additions relating to any such tax, duty, charge or
assessment.
Tax Return
means any return, report, information statement, or similar statement required to
be filed with respect to any Taxes (including any attached schedules), including, without
limitation, any information return, claim for refund, amended return and declaration of estimated
Tax.
Underwriting Agreement
has the meaning set forth in
Section 9.1(d)
hereto.
Yorktown VII
has the meaning set forth in the introductory paragraph hereto.
Yorktown Note
means that certain Convertible Promissory Note dated June 25, 2007 in the
principal amount of $10,000,000 payable by AOG to Yorktown VII.
8
ARTICLE II.
CONTRIBUTION TRANSACTION
2.1
Contribution of AOG Common Stock to ARI
. Subject to
Section 2.8
, immediately prior
to the Effective Time, each AOG Stockholder shall contribute all of its shares of AOG Common Stock
to ARI in exchange for the number of shares of ARI Common Stock set forth opposite such Persons
name in the table below:
|
|
|
|
|
|
|
|
|
|
|
Number of AOG Shares
|
|
Number of ARI
|
|
|
Owned and to be
|
|
Shares to be
|
Stockholder
|
|
Contributed to ARI
|
|
Received
|
Yorktown Energy Partners V, L.P.
|
|
|
25,000
|
|
|
|
54,964
|
|
Yorktown Energy Partners VI, L.P.
|
|
|
125,000
|
|
|
|
274,755
|
|
2.2
Contribution of Neo Canyon Assets to ARI
. Subject to
Section 2.8
,
immediately prior to the Effective Time, Neo Canyon shall contribute, transfer and assign to ARI
all of its right, title and interest in and to the Neo Canyon Oil and Gas Properties, and ARI shall
acquire the Neo Canyon Oil and Gas Properties in exchange for 1,413,081 shares of ARI Common Stock.
2.3
Contribution of Lubar Note to ARI
. Immediately prior to the Effective Time, Lubar
shall contribute to ARI the Lubar Note in exchange for that number of shares of ARI Common Stock
into which the Lubar Note is convertible on the IPO Conversion Date (as such term is defined in the
Lubar Note).
2.4
Contribution of Yorktown Note to ARI
. Immediately prior to the Effective Time,
Yorktown VII shall contribute to ARI the Yorktown Note in exchange for that number of shares of ARI
Common Stock into which the Yorktown Note is convertible on the IPO Conversion Date (as such term
is defined in the Yorktown Note).
2.5
Issuance of New Certificates.
At the Effective Time, ARI shall issue to each AOG
Stockholder, Neo Canyon, Lubar and Yorktown VII a certificate or certificates representing the
number each of shares of ARI Common Stock to be issued to such Person pursuant to
Sections
2.1
,
2.2
,
2.3
and
2.4
, subject to adjustment as provided in
Section
2.8
. Each such certificate shall be registered in the name of the Person or Persons specified
by the recipient thereof to ARI in writing at least two (2) Business Days prior to the Closing.
2.6
Certificate Legends.
The certificates evidencing the ARI Common Stock delivered
pursuant to
Section 2.5
shall bear a legend substantially in the form set forth below and
containing such other information as ARI may deem necessary or appropriate:
THE SECURITIES REPRESENTED HEREBY HAVE NOT BEEN REGISTERED UNDER THE SECURITIES ACT
OF 1933, AS AMENDED, OR
9
ANY STATE SECURITIES LAWS, AND NEITHER THE SECURITIES NOR
ANY INTEREST THEREIN MAY BE OFFERED, SOLD, TRANSFERRED, PLEDGED OR OTHERWISE
DISPOSED OF EXCEPT PURSUANT TO AN EFFECTIVE REGISTRATION STATEMENT UNDER SUCH ACT
AND
SUCH LAWS OR PURSUANT TO AN EXEMPTION THEREFROM WHICH, IN THE OPINION OF COUNSEL FOR
THE HOLDER, WHICH COUNSEL AND OPINION ARE REASONABLY SATISFACTORY TO COUNSEL FOR
THIS CORPORATION, IS AVAILABLE.
2.7
Fractional Shares.
No fractional shares of ARI Common Stock or scrip shall be
issued as a result of the transactions contemplated by
Sections 2.3
,
2.4
and
2.8
. Any fractional share of ARI Common Stock which would otherwise be issuable as a
result of the such transactions shall be rounded up to the nearest whole share.
2.8
Certain Adjustments.
The ARI Board may adjust the number of shares of ARI Common
Stock to be issued to each AOG Stockholder and to Neo Canyon pursuant to
Sections 2.1
and
2.2
in order to reflect a capitalization of ARI that the ARI Board reasonably determines to
be in the best interests of ARI and its stockholders (including the AOG Stockholders and Neo
Canyon) based on (i) the actual pricing of the ARI Initial Public Offering, (ii) the number of
shares of ARI Common Stock issuable pursuant to Sections
2.3
and
2.4
and (iii)
subject to
Section 10.1(d)
, the relative net asset valuations (as determined in the
reasonable business judgment of the ARI Board using the same valuation methodology for ARI Oil and
Gas Properties and Neo Canyon Oil and Gas Properties) of ARI, AOG and the Neo Canyon Oil and Gas
Properties after giving effect to any financing transactions and acquisitions consummated by AOG or
ARI (in each case to have been approved by the AOG Board or the ARI Board, as applicable) after the
execution of this Contribution Agreement and before the Effective Time.
2.9
Proration of Costs and Revenues
. Except as otherwise expressly set forth in this
Contribution Agreement, ARI shall be entitled to all production of Hydrocarbons from or
attributable to the Neo Canyon Oil and Gas Properties at and after the Closing Date (and all
products and proceeds attributable thereto) and to all other income, proceeds, receipts and credits
earned with respect to the Neo Canyon Oil and Gas Properties at or after the Closing Date, and
shall be responsible for (and entitled to any refunds with respect to) all Property Costs incurred
at and after the Closing Date. Neo Canyon shall be entitled to all production of Hydrocarbons from
or attributable to the Neo Canyon Oil and Gas Properties prior to the Closing Date (and all
products and proceeds attributable thereto), and to all other income, proceeds, receipts and
credits earned with respect to the Neo Canyon Oil and Gas Properties prior to the Closing Date, and
shall be responsible for (and entitled to any refunds with respect to) all Property Costs incurred
prior to the Closing Date. Earned and incurred, as used in this Contribution Agreement, shall
be interpreted in accordance with GAAP and the Council of Petroleum Accountant Societies (COPAS)
standards.
2.10
Receipts Not Reflected
. Except as otherwise provided in this Contribution
Agreement, any production of Hydrocarbons from or attributable to the Neo Canyon Oil and Gas
Properties (and all products and proceeds attributable thereto) and any other income, proceeds and
receipts earned with respect to the Neo Canyon Oil and Gas Properties shall be treated as follows:
(i) all production of Hydrocarbons from or attributable to the Oil and Gas Properties
10
(and all
products and proceeds attributable thereto) and all other income, proceeds and receipts earned with
respect to the Oil and Gas Properties to which ARI is entitled under
Section 2.9
shall be
the sole property and entitlement of ARI, and, to the extent received by Neo Canyon, Neo Canyon
shall fully disclose, account for and remit the same promptly to ARI, and (ii) all production of
Hydrocarbons from or attributable to the Neo Canyon Oil and Gas Properties (and all products
and proceeds attributable thereto) and all other income, proceeds and receipts earned with respect
to the Neo Canyon Oil and Gas Properties to which Neo Canyon is entitled under
Section 2.9
shall be the sole property and entitlement of Neo Canyon and, to the extent received by ARI, ARI
shall fully disclose, account for and remit the same promptly to Neo Canyon.
2.11
Expenses Not Reflected.
Except as otherwise provided in this Contribution
Agreement, any Property Costs shall be treated as follows: (i) all Property Costs for which Neo
Canyon is responsible under
Section 2.9
shall be the sole obligation of Neo Canyon and Neo
Canyon shall promptly pay, or if paid by ARI, promptly reimburse ARI for and hold ARI harmless from
and against same; and (ii) all Property Costs for which ARI is responsible under
Section
2.9
shall be the sole obligation of ARI and ARI shall promptly pay, or if paid by Neo Canyon,
promptly reimburse Neo Canyon for and hold Neo Canyon harmless from and against same. Neo Canyon
is entitled to resolve all joint interest audits and other audits of Property Costs covering
periods for which Neo Canyon is responsible under the terms of this Contribution Agreement. ARI is
entitled to resolve all joint interest audits and other audits of Property Costs covering periods
for which ARI is in whole or in part responsible, provided that ARI shall not agree to any
adjustments to previously assessed costs for which Neo Canyon is liable without the prior written
consent of Neo Canyon, such consent not to be unreasonably withheld. ARI shall provide Neo Canyon
with a copy of all applicable audit reports and written audit agreements received by ARI and
relating to periods for which Neo Canyon is partially responsible.
2.12
Transfer Taxes.
All transfer, documentary, sales, use, stamp, registration and
other such taxes and fees (Transfer Taxes) incurred in connection with the contribution
transaction contemplated by Article II of this Contribution Agreement shall be borne 70% by ARI and
AOG on the one hand, and 30% by Neo Canyon on the other; provided, that such allocations shall be
adjusted proportionately with any adjustments made pursuant to
Section 2.9
. The parties
shall reasonably cooperate with each other to provide any information and documentation reasonably
requested that may be necessary to obtain any exemption from any Transfer Taxes.
ARTICLE III.
CLOSING
3.1
Time and Place.
The closing of the transactions contemplated hereby (the
Closing
) shall be held at the offices of Thompson & Knight LLP, 1700 Pacific Avenue, Dallas,
Texas 75201 at 10:00 a.m., Dallas time, immediately prior to the Effective Time; provided that all
of the conditions contained in
Article IX
have been satisfied or waived, or at such other
place or time as the parties hereto may mutually agree. The date of the Closing is referred to
herein as the
Closing Date
.
11
3.2
Deliveries at Closing.
Subject to the provisions of
Article IX
hereof, at
the Closing there shall be delivered the certificates and other documents required to be delivered
pursuant to
Article IX
hereof.
ARTICLE IV.
REPRESENTATIONS AND WARRANTIES OF AOG
AOG represents and warrants to ARI and Neo Canyon that the statements contained in this
Article IV
are correct and complete as of the date hereof (it being recognized that each
such representation and warranty with respect to AOGs operations and the AOG Oil and Gas
Properties shall be deemed to refer to AOG and each of its Subsidiaries, taken as a whole).
4.1
Organization and Power.
Each of AOG and its Subsidiaries is duly incorporated or
formed (as the case may be), validly existing and in good standing (as applicable) under the Laws
of its respective jurisdiction of incorporation or formation, and is qualified and in good standing
to transact business in each jurisdiction in which such qualification is required by Law, except
where the failure to be so qualified would not have an ARI Material Adverse Effect. AOG has all
requisite corporate power and authority to execute, deliver and perform its obligations under this
Contribution Agreement and to consummate the transactions contemplated hereby. AOG has heretofore
delivered or made available to ARI and Neo Canyon complete and correct copies of (a) its
certificate of incorporation and bylaws, each as amended to date, and (b) its Subsidiaries
respective certificates of incorporation and bylaws, or other comparable organizational documents,
each as amended to date.
4.2
Authorizations; Execution and Validity.
The execution and delivery of this
Contribution Agreement by AOG, the performance of this Contribution Agreement by AOG and the
consummation by AOG of the transactions contemplated hereby and thereby to be consummated by it,
have been duly authorized by all necessary corporate action and no other corporate action on the
part of AOG is necessary with respect thereto. This Contribution Agreement has been duly executed
and delivered by AOG and, when duly and validly executed and delivered, will constitute a valid and
binding obligation of AOG and is enforceable against and AOG in accordance with its terms, except
as such enforceability may be limited by bankruptcy, insolvency, reorganization and similar Laws
affecting creditors generally and by the availability of equitable remedies.
4.3
Capitalization.
(a) The authorized capital stock of AOG consists solely of 1,000,000 shares of AOG Common
Stock and 100,000 shares of AOG Preferred Stock. As of the date hereof, there are an aggregate of
150,000 shares of AOG Common Stock issued and outstanding, all of which shares are owned of record
and beneficially by the AOG Stockholders with each AOG Stockholder owning the number of shares set
forth in
Section 2.1
hereto, and have been duly authorized and validly issued, and are
fully-paid and non-assessable. No shares of AOG Preferred Stock are issued and outstanding. As of
the date hereof, the issued and outstanding amount of AOG Common Stock on a fully diluted basis is
150,000 shares. Except as contemplated by the Lubar Note, the Yorktown Note, future issuances of
equity or convertible
12
debt in connection with financing transactions or acquisitions that the AOG
Board reasonably determines to be in the best interests of AOG and its stockholders, and with
respect to options, warrants, rights or other equity based awards issued as part of reasonable
compensation plans approved by the AOG Board, as of the Closing Date, there shall be no outstanding
options, subscriptions, warrants,
calls, commitments, pre-emptive rights or other rights obligating AOG to issue or sell any
shares of its capital stock or any securities convertible into or exercisable for any shares of its
capital stock, or otherwise requiring AOG to give any Person the right to receive any benefits or
rights similar to any rights enjoyed by or accruing to the holders of shares of capital stock of
AOG or any rights to participate in the equity or net income of AOG. All of the issued shares of
AOGs capital stock were issued, and to the extent purchased or transferred, have been so purchased
or transferred, in compliance with all applicable Laws, including federal and state securities
Laws, and any preemptive rights and any other statutory or contractual rights of any AOG
Stockholder.
(b) AOG has no Subsidiaries other than those set forth on
Schedule 4.3(b)
. AOG,
directly or indirectly, owns all capital of and other equity interests in its Subsidiaries, and
there are no outstanding options, subscriptions, warrants, calls, commitments, pre-emptive rights
or other rights in favor of any Person other than AOG or other AOG Subsidiaries obligating AOG or
any of its Subsidiaries to issue or sell any shares or other equity interests of any of AOGs
Subsidiaries or any securities convertible into or exercisable for any shares or other equity
interests of any such Subsidiary, or otherwise requiring AOG or any of its Subsidiaries to give any
Person (other than AOG or any of its Subsidiaries) the right to receive any benefits or rights
similar to any rights enjoyed by or accruing to the holders of shares or other equity interests of
any such Subsidiary or any rights to participate in the equity or net income of any such
Subsidiary. AOG does not own, directly or indirectly, any capital of or other equity interest in
or have any other investment in any other Person other than its Subsidiaries. Except as otherwise
set forth on
Schedule 4.3(c)
, there are no stockholders agreements, voting trusts or other
agreements or understandings between or among AOG Stockholders or to which AOG is a party or by
which it is bound with respect to the transfer or voting of any capital stock of AOG, none of which
shall be in effect following the Closing.
4.4
Financial Statements; Other Financial Data.
Attached hereto on
Schedule
4.4
are correct and complete copies of the audited consolidated balance sheet of AOG and its
Subsidiaries as of December 31, 2006 with the related consolidated statements of operations,
changes in stockholders equity, and cash flows for the year then ended (the
AOG Audited Financial
Statements
) and the unaudited consolidated balance sheet of AOG and its Subsidiaries as of March
31, 2007 (the
AOG Unaudited Balance Sheet
and, together with the AOG Audited Financial
Statements, the
AOG Financial Statements
). The AOG Financial Statements present fairly in all
material respects the financial position of AOG as of the dates indicated, and the results of its
operations for the respective periods indicated. The AOG Audited Financial Statements are in
conformity with GAAP, consistently applied. The AOG Unaudited Balance Sheet is unaudited and,
therefore, is subject to normal recurring year-end adjustments and the absence of footnotes.
4.5
Consents.
Neither the execution and delivery by AOG of this Contribution
Agreement nor the consummation or performance by AOG of the transactions contemplated by this
Contribution Agreement to be consummated or performed by it will require prior to the
13
Closing (on
the part of AOG) any consent from, authorization or approval or other action by, notice to or
declaration, filing or a registration with, any Governmental Authority or any other third party,
except, if required, to comply with the HSR Act or as specified in
Schedule 4.5
.
4.6
No Defaults or Conflicts.
Neither the execution and delivery by AOG of this
Contribution Agreement nor the consummation or performance by AOG of the transactions contemplated
by this Contribution Agreement to be consummated or performed by it (i) results or will result in
any violation of the certificate of incorporation or bylaws of AOG or other organizational or
governing documents of AOG or any of its Subsidiaries; or (ii) violates or conflicts with, or
constitutes a breach of any of the terms or provisions of or a default under, or results in the
creation or imposition of any Lien upon any property or asset of AOG, the trigger of any charge,
payment or requirement of consent, or the acceleration or increase of the maturity of any payment
date under: (A) any Material Contract to which AOG is a party or (B) any applicable Law or Order to
which AOG or any of its respective properties is subject, other than, in each case, where such
failure, conflict or breach would not have an ARI Material Adverse Effect.
4.7
Agreements, Contracts and Commitments.
AOG has listed in
Schedule 4.7
all
Material Contracts to which it is a party (true and correct copies of each such document have been
previously delivered or made available to ARI and Neo Canyon). Except as set forth in
Schedule
4.7
, AOG has not breached, nor to AOGs Knowledge is there any claim or any legal basis for a
claim that AOG or any third party has breached, any of the terms or conditions of any Material
Contract if any such breach, whether considered individually or in the aggregate, could result in
the imposition of damages or the loss of benefits in an amount or of a kind that would have an ARI
Material Adverse Effect to AOG and its Subsidiaries taken as a whole.
4.8
Litigation.
Schedule 4.8
lists all Legal Proceedings pending or, to AOGs
Knowledge, threatened against or affecting AOG or any of its assets. Except as disclosed on
Schedule 4.8
, AOG is not subject to any Order. There are no Legal Proceedings pending
against or, to AOGs Knowledge, threatened in writing against, AOG that questions the validity or
legality of any of this Contribution Agreement or any action taken or to be taken by AOG in
connection herewith or therewith.
4.9
ERISA Compliance; Labor.
(a) Except as set forth on
Schedule 4.9
, neither AOG nor any other entity required to
be aggregated with AOG under Section 414 of the Code (the
Aggregated Group
) including AOG
sponsors, maintains or contributes to any Employee Benefit Plan.
(b) No labor associations, organizations, or unions have been certified to represent any
employee of AOG, and no collective bargaining agreement or other labor union contract has been
requested by any employee or group of employees of AOG, and no discussions or negotiations with
respect to any such agreement or contract have occurred.
(c) AOG and its Subsidiaries are in material compliance with all Laws, rules, regulations and
Orders relating to the employment of labor, including all such Laws, rules, regulations and Orders
relating to wages, hours, collective bargaining, discrimination, civil
14
rights, safety and health,
workers compensation and the collection and payment of withholding or Social Security Taxes and
similar Taxes.
4.10
Taxes.
Except as disclosed on
Schedule 4.10
:
(a) All material Tax Returns required to be filed on or before the Closing Date by or on
behalf of AOG have been or will be filed within the time prescribed by Law (including extensions of
time permitted by Law) and such Tax Returns are true, correct, complete and accurate in all
material respects and reflect accurately in all material respects all liability for Taxes of AOG or
any of its Subsidiaries.
(b) AOG has paid, on a timely basis, all material Taxes of AOG and of any of its Subsidiaries
that are due on or before December 31, 2006, and will have paid all material Taxes of AOG and of
any of its Subsidiaries that are due on or before the Closing Date.
(c) The provision for Taxes and other accrued Tax liabilities reflected in the Financial
Statements are sufficient to cover all material liabilities for Taxes in respect of Tax Periods
ending at or prior to the relevant Financial Statement date.
(d) There are no Liens for Taxes upon any of the properties or assets of AOG or of any of its
Subsidiaries (except for Permitted Liens).
(e) There are no pending Orders, audits, actions, proceedings, investigations, disputes or
claims instigated by any Governmental Authority with respect to any Taxes payable by or asserted
against AOG or any of its Subsidiaries. Neither AOG nor any of its Subsidiaries has received
notice from any taxing authority of its intent to examine or audit any of its Tax Returns.
(f) Neither AOG nor any of its Subsidiaries is subject to Tax or has done business in any
country other than the United States.
(g) No agreements relating to allocation or sharing of, or liability or indemnification for,
Taxes exist between AOG or any of its Subsidiaries and any other Person. Any internal tax
allocation agreement shall terminate at the Closing.
(h) All Taxes required to be withheld, collected or deposited by AOG or any of its
Subsidiaries (including, without limitation, amounts required to be withheld, collected or
deposited with respect to amounts paid or owing to any employee, creditor, independent contractor
or other Person) have been timely withheld, collected or deposited and, to the extent required,
have been timely paid to the relevant taxing authority.
(i) Neither AOG nor any of its Subsidiaries has made any payments, is obligated to make any
payments, or is a party to any agreement that could obligate it to make any payments that will not
be deductible under Section 280G of the Code.
(j) There are no outstanding agreements or waivers that would extend the statutory period in
which a taxing authority may assess or collect a Tax against AOG or any of its Subsidiaries.
15
4.11
Brokers.
AOG has not paid or become obligated to pay any fee or commission to
any broker, finder or intermediary in connection with the transactions contemplated hereby for
which AOG, ARI or Neo Canyon shall have liability following the Closing.
4.12
Absence of Certain Changes or Events.
Except as set forth on
Schedule
4.12
or as disclosed in the AOG Audited Financial Statements or the AOG Unaudited Balance Sheet
or as contemplated by the Lubar Note or the Yorktown Note, since March 31, 2007, there has not been
any transaction or occurrence in which AOG has:
(a) suffered any Material Adverse Effect;
(b) declared, set aside or paid any dividend or other distribution (whether in cash, stock or
property) with respect to any of its outstanding capital stock, or made any redemption, purchase or
other acquisition of any of its equity securities;
(c) cancelled any debts or waived any receivables, claims or rights in excess of $500,000
individually;
(d) suffered any uninsured casualty loss or damage in excess of $500,000 individually;
(e) amended any term of any equity security of AOG other than as contemplated by this
Contribution Agreement; or
(f) made any change in its accounting methods, principles or practices.
4.13
Compliance with Laws.
AOG holds all material Permits necessary for the lawful
conduct of its business and is in compliance in all material respects, with all Laws and Orders
applicable to its business and has filed with the proper authorities all statements and reports
required by the Laws and Orders to which AOG or any of its properties or operations are subject.
No claim has been made by any Governmental Authority (and, to AOGs Knowledge, no such claim is
anticipated) to the effect that the business conducted by AOG fails to comply, in any respect, with
any Law.
4.14
Transactions with Related Parties.
Except for transactions with any of AOGs
Subsidiaries and as otherwise set forth on
Schedule 4.14
:
(a) No Affiliate has entered into, or has had any direct or indirect financial interest in,
any AOG Material Contract, transaction or business dealings involving AOG;
(b) No Affiliate owns or has any interest in, directly or indirectly, in whole or in part, any
tangible or intangible property used in the conduct of the business of AOG;
(c) Other than amounts owed to AOG pursuant to any intercompany debts, joint interest billing
and general and administrative allocations, or expense advance reimbursements in the ordinary
course of business, no Affiliate owes any money to, nor is any such Affiliate owed any money by,
AOG other than as set forth in this Contribution Agreement; and
16
(d) AOG has not, directly or indirectly, guaranteed or assumed any indebtedness for borrowed
money or otherwise for the benefit of any Affiliate of AOG.
4.15
Agents.
Except as set forth on
Schedule 4.15
, AOG has not designated or
appointed any person or other entity to act for it or on its behalf pursuant to any power of
attorney or any agency which is presently in effect (other than such of AOGs directors, officers
and employees to whom AOG has given the authority to act for AOG in the ordinary course of its
business) or shall continue after the Closing Date.
4.16
Books and Records.
The minute books and records of AOG are current as of the
date hereof (and shall be current as of the Closing) with respect to all undertakings and
authorizations, and contain a true, complete and correct record of all actions taken at all
meetings and by all written consents in lieu of meetings of AOGs board of directors, or any
committees thereof, and AOG Stockholders. The stock ledger and related stock transfer records of
AOG contain a true, complete and correct record of the original issuance, transfer and other
capitalization matters of the capital stock of AOG. The accounting, financial reporting, tax and
business books and records of AOG accurately and fairly reflect in all material respects the
business and condition of AOG and the transactions and the assets and liabilities of AOG with
respect thereto. Without limiting the generality of the foregoing, AOG has not engaged in any
transaction with respect to its business or operations, maintained any bank account therefor or
used any funds of AOG in the conduct thereof except for transactions, bank accounts and funds that
have been and are reflected in the normally maintained books and records of the business.
4.17
Information Furnished.
AOG has made available to ARI and Neo Canyon and their
respective directors, officers, employees, counsel, representatives, financing sources, customers,
creditors, accountants and auditors, true and correct copies of all agreements, documents, and
other items listed on the Schedules to this Contribution Agreement and all books and records of
AOG.
4.18
Directors and Officers.
Schedule 4.18
lists all of the directors and
officers of AOG as of the date hereof.
4.19
Bank Accounts.
Attached hereto as
Schedule 4.19
is a list of all banks
or other financial institutions with which AOG has an account, showing the type and account number
of each such account.
4.20
Owned Real Property.
Other than the AOG Oil and Gas Properties, AOG does not own
any real property.
4.21
Leased Real Property.
Other than the AOG Oil and Gas Properties,
Schedule
4.21
contains a complete and correct list of all real property leases and any and all
amendments thereto relating to the leased real property to which AOG is a party or is bound (the
Real Property Leases
). AOG has provided or made available to ARI and Neo Canyon correct and
complete copies of the Real Property Leases. Except as disclosed in
Schedule 4.21
, (i)
each of the Real Property Leases is in full force and effect, and, to AOGs Knowledge, is
enforceable against the landlord which is party thereto in accordance with its terms (except as
such enforceability may be limited by bankruptcy, insolvency, reorganization and similar laws
17
affecting creditors generally and by the availability of equitable remedies), (ii) there are no
subleases under the Real Property Leases and none of the Real Property Leases has been assigned
(other than collateral assignments to AOGs Senior Lender), (iii) no notices of default
or notices of termination have been received by AOG with respect to the Real Property Leases
which have not been withdrawn or canceled and (iv) AOG is not, and to AOGs Knowledge, no other
party is, in default under any Real Property Lease. There is no AOG Knowledge of, nor has there
been receipt of any written notice of a proceeding in eminent domain or other similar proceeding
affecting property listed on
Schedule 4.21
.
4.22
Insurance.
Schedule 4.22
contains a true and complete list of all
insurance policies, directors and officers liability policies, and formal self-insurance programs,
and other forms of insurance and all fidelity bonds held by or applicable to AOG and its owned or
leased properties.
Schedule 4.22
describes (a) whether each insurance policy listed on
Schedule 4.22
is occurrence-based or claims made based and (b) each pending claim
thereunder for more than $500,000 per claim and a history of all such claims made against any such
insurance policy of AOG for the past three (3) years. All insurance policies listed on
Schedule 4.22
have been made available to ARI and Neo Canyon and are subject to the
deductibles or retentions referenced on
Schedule 4.22
. AOG maintains insurance for its
benefit, in coverages and amounts to be customary and adequate in the oil and gas industry. AOG is
not in default with respect to any provision in any current policy maintained for its benefit, and
all such insurance is in full force and effect. AOG has not received, nor is there any AOG
Knowledge of, any notice of cancellation or nonrenewal of any such insurance policy. AOG has not
failed to give any notice or present any claim for more than $500,000 under any of the policies for
the benefit of AOG in due and timely fashion. AOG has not been refused any insurance with respect
to its assets, properties or businesses, nor has any such coverage been materially limited by any
insurance carrier to which AOG has applied for any such insurance or with which AOG has carried
insurance during the past three (3) years. Other than as described on
Schedule 4.22
, no
further payments of premiums will be due following the Closing by AOG with respect to insurance
coverages prior to the Closing. Neither this Contribution Agreement nor any of the transactions
contemplated by this Contribution Agreement to occur at the Closing will adversely affect AOGs
coverage under the terms of the insurance policies with respect to periods prior to the Closing.
4.23
Title to Oil and Gas Properties.
AOG has Defensible Title to all AOG Oil and Gas
Properties. All proceeds from the sale of AOGs share of the Hydrocarbons being produced from the
AOG Oil and Gas Properties are currently being paid in full to AOG by the purchasers thereof on a
timely basis, and none of such proceeds are currently being held in suspense by such purchaser or
any other party, except as set forth in
Schedule 4.23
.
4.24
Environmental Matters.
Except as set forth in
Schedule 4.24
:
(a) to AOGs Knowledge, it has conducted its business and operated its assets, and is
conducting its business and operating its assets, and the condition of all facilities and
properties (including off site storage or disposal of any Hazardous Materials from such facilities
or properties) currently or formerly owned, leased or operated by AOG is, in material compliance
with all Environmental Laws;
18
(b) AOG has not been notified by any Governmental Authority or other third party that any of
the operations or assets of AOG is the subject of any investigation or inquiry by any Governmental
Authority or other third party evaluating whether any material remedial action is
needed to respond to a release or threatened release of any Hazardous Material or to the
improper storage or disposal (including storage or disposal at offsite locations) of any Hazardous
Material where such investigation or inquiry has not been fully resolved and satisfied as of the
date hereof;
(c) neither AOG nor, to AOGs Knowledge, any other Person has filed any notice under any
federal, state or local Law indicating that (i) AOG is responsible for the improper release into
the environment, or the improper storage or disposal, of any Hazardous Material, or (ii) any
Hazardous Material is improperly stored or disposed of upon any property of AOG;
(d) to AOGs Knowledge, it does not have any material liability (contingent or otherwise) in
connection with (i) the release or threatened release into the environment at, beneath or on any
property now or previously owned or leased by AOG, or (ii) the storage or disposal of any Hazardous
Material;
(e) AOG has not received any claim, complaint, notice, inquiry or request for information
involving any matter which remains unresolved as of the date hereof with respect to any alleged
violation of any Environmental Law or regarding current or potential liability under any
Environmental Law or any personal injury, property damage or natural resource damage claim relating
to operations or conditions of any facilities or property (including off site storage or disposal
or release of any Hazardous Material from such facilities or property) currently or formerly owned,
leased or operated by AOG;
(f) to AOGs Knowledge, no property now or previously owned, leased or operated by AOG is
listed on the National Priorities List pursuant to CERCLA or on the CERCLIS or on any other federal
or state list as sites requiring investigation or cleanup;
(g) to AOGs Knowledge, it is not directly transporting, has not directly transported, is not
directly arranging for the transportation of, or has not directly transported, any Hazardous
Material to any location which is listed on the National Priorities List pursuant to CERCLA, on the
CERCLIS, or on any similar federal or state list or which is the subject of federal, state or local
enforcement actions or other investigations that may lead to material claims against AOG for
remedial work, damage to natural resources or personal injury, including claims under CERCLA;
(h) except for the draining and backfilling of pits associated with drilling activities in the
ordinary course, there are no sites, locations or operations at which AOG is obligated to
undertake, is currently undertaking, or has completed, any remedial or response action relating to
any disposal or release, as required by Environmental Laws; and
(i) AOG does not own or operate any underground storage tanks or solid waste disposal
facilities.
19
4.25
Patents, Trademarks and Similar Rights.
AOG owns or is properly licensed to use
or otherwise has rights to use all Intellectual Property (specifically including any seismic
license or Permit) material to the operations of the business of AOG as currently conducted. To
AOGs Knowledge, except as set forth on
Schedule 4.25
, (i) the entry into this Contribution
Agreement and the transactions contemplated hereby will not have any effect on any contracts
related to
Intellectual Property, and (ii) neither AOG nor, to AOGs Knowledge, any other party, is in
breach of or default under any Intellectual Property license or any other contract or legal
requirement relating to the Intellectual Property, in each such case.
ARTICLE V.
REPRESENTATIONS AND WARRANTIES OF NEO CANYON
Each of Neo Canyon and Neo Canyon GP jointly and severally represents and warrants to ARI,
AOG, the AOG Stockholders, Lubar and Yorktown VII that the statements contained in this
Article
V
are correct and complete as of the date hereof.
5.1
Organization and Power.
Neo Canyon is duly formed (as the case may be), validly
existing and in good standing (as applicable) under the Laws of its jurisdiction of formation, and
is qualified and in good standing to transact business in each jurisdiction in which such
qualification is required by Law, except where the failure to be so qualified would not have an ARI
Material Adverse Effect. Neo Canyon has all requisite corporate power and authority to execute,
deliver and perform its obligations under this Contribution Agreement and to consummate the
transactions contemplated hereby. Neo Canyon and Neo Canyon GP have heretofore delivered or made
available to ARI, AOG, the AOG Stockholders, Lubar and Yorktown VII their respective certificates
of formation, partnership or operating agreements or other comparable organizational documents,
each as amended to date.
5.2
Authorization; Execution and Validity.
The execution and delivery of this
Contribution Agreement by Neo Canyon, the performance of this Contribution Agreement by Neo Canyon
and the consummation by Neo Canyon of the transactions contemplated hereby and thereby to be
consummated by it, have been duly authorized by all necessary corporate action and no other
corporate action on the part of Neo Canyon is necessary with respect thereto. This Contribution
Agreement has been duly executed and delivered by Neo Canyon and, when duly and validly executed
and delivered, will constitute a valid and binding obligation of Neo Canyon and is enforceable
against Neo Canyon in accordance with its terms, except as such enforceability may be limited by
bankruptcy, insolvency, reorganization and similar Laws affecting creditors generally and by the
availability of equitable remedies.
5.3
Consents.
Neither the execution and delivery by Neo Canyon of this Contribution
Agreement nor the consummation or performance by Neo Canyon of the transactions contemplated by
this Contribution Agreement to be consummated or performed by it will require prior to the Closing
(on the part of Neo Canyon) any consent from, authorization or approval or other action by, notice
to or declaration, filing or a registration with, any Governmental Authority or any other third
party, except, if required, to comply with the HSR Act or as specified in
Schedule 5.3
.
20
5.4
No Defaults or Conflicts.
Neither the execution and delivery by Neo Canyon of
this Contribution Agreement nor the consummation or performance by Neo Canyon of the transactions
contemplated by this Contribution Agreement to be consummated or performed by it (i) results or
will result in any violation of the certificate of limited partnership or agreement of limited
partnership of Neo Canyon or other organizational or governing documents of Neo
Canyon or any of its Subsidiaries; or (ii) violates or conflicts with, or constitutes a breach
of any of the terms or provisions of or a default under, or results in the creation or imposition
of any Lien upon any property or asset of Neo Canyon, the trigger of any charge, payment or
requirement of consent, or the acceleration or increase of the maturity of any payment date under:
(A) any Material Contract to which Neo Canyon is a party or (B) any applicable Law or Order to
which Neo Canyon or any of its respective properties is subject, other than, in each case, where
such failure, conflict or breach would not have an ARI Material Adverse Effect.
5.5
Brokers.
Neo Canyon has not paid or become obligated to pay any fee or commission
to any broker, finder or intermediary in connection with the transactions contemplated hereby for
which ARI, AOG, the AOG Stockholders or Neo Canyon shall have liability following the Closing.
5.6
Litigation.
Schedule 5.6
lists all Legal Proceedings pending or, to Neo
Canyons Knowledge, threatened against or affecting Neo Canyon or any of its assets. Except as
disclosed on
Schedule 5.6
, Neo Canyon is not subject to any Order. There are no Legal
Proceedings pending against or, to Neo Canyons Knowledge, threatened in writing against, Neo
Canyon that questions the validity or legality of any of this Contribution Agreement or any action
taken or to be taken by Neo Canyon in connection herewith or therewith.
5.7
Title to the Neo Canyon Oil and Gas Properties.
Neo Canyon has Defensible Title
to all of the Neo Canyon Oil and Gas Properties. All proceeds from the sale of the Hydrocarbons
being produced from the Neo Canyon Oil and Gas Properties are currently being paid in full to Neo
Canyon by the purchasers thereof on a timely basis, and none of such proceeds are currently being
held in suspense by such purchaser or any other party, except as set forth in
Schedule 5.7
.
5.8
Environmental Matters.
Except as set forth in
Schedule 5.8
:
(a) to Neo Canyons Knowledge, the Neo Canyon Oil and Gas Properties have been and are being
operated in compliance with all Environmental Laws;
(b) Neo Canyon has not been notified by any Governmental Authority or other third party that
any of the Neo Canyon Oil and Gas Properties are the subject of any investigation or inquiry by any
Governmental Authority or other third party evaluating whether any material remedial action is
needed to respond to a release or threatened release of any Hazardous Material or to the improper
storage or disposal (including storage or disposal at offsite locations) of any Hazardous Material
where investigation or inquiry remains unresolved as of the date hereof;
(c) neither Neo Canyon nor, to Neo Canyons Knowledge, any other Person has filed any notice
under any federal, state or local Law indicating that (i) Neo Canyon is
21
responsible for the
improper release into the environment, or the improper storage or disposal, of any Hazardous
Material, or (ii) any Hazardous Material is improperly stored or disposed of upon the Neo Canyon
Oil and Gas Properties;
(d) to Neo Canyons Knowledge, Neo Canyon does not have any material liability (contingent or
otherwise) in connection with (i) the release or threatened release into the environment at,
beneath or on the Neo Canyon Oil and Gas Properties, or (ii) the storage or disposal of any
Hazardous Material thereon;
(e) Neo Canyon has not received any claim, complaint, notice, inquiry or request for
information involving any matter which remains unresolved as of the date hereof with respect to any
alleged violation of any Environmental Law or regarding current or potential liability under any
Environmental Law or any personal injury, property damage or natural resource damage claim relating
to operations or conditions of the Neo Canyon Oil and Gas Properties (including off site release of
any Hazardous Material from the Neo Canyon Oil and Gas Properties);
(f) to Neo Canyons Knowledge, none of the Neo Canyon Oil and Gas Properties are listed on the
National Priorities List pursuant to CERCLA or on the CERCLIS or on any other federal or state list
as sites requiring investigation or cleanup;
(g) to Neo Canyons Knowledge, Neo Canyon is not directly transporting, has not directly
transported, is not directly arranging for the transportation of, or has not directly transported,
any Hazardous Material to any location which is listed on the National Priorities List pursuant to
CERCLA, on the CERCLIS, or on any similar federal or state list or which is the subject of federal,
state or local enforcement actions or other investigations that may lead to material claims against
the Neo Canyon Oil and Gas Properties for remedial work, damage to natural resources or personal
injury, including claims under CERCLA; and
(h) there are no sites, locations or operations with respect to the Neo Canyon Oil and Gas
Properties at which Neo Canyon is obligated to undertake, is currently undertaking, or has
completed, any remedial or response action relating to any disposal or release, as required by
Environmental Laws.
5.9
Taxes and Assessments
Neo Canyon has caused to be timely filed all material Tax returns relating to the Neo
Canyon Oil and Gas Properties the failure to pay which could result in the placement of a Lien on
all or a portion of the Neo Canyon Oil and Gas Properties. Neo Canyon has paid or caused to be
paid all ad valorem, property, production, severance and similar Taxes based upon or measured by
the ownership of or the production of Hydrocarbons from the Oil and Gas Properties, except those
being contested in good faith and disclosed to ARI in writing. Neo Canyon has not received written
notice of any pending claim against Neo Canyon from any applicable taxing authority for assessment
of Taxes with respect to the Neo Canyon Oil and Gas Properties. There are no audits of Neo Canyon
by any applicable taxing authority with respect to Taxes attributable to the Neo Canyon Oil and Gas
Properties. Except for statutory liens for property taxes and ad valorem taxes not yet due and
payable, there are no tax liens on or with respect to the Neo Canyon Oil and Gas Properties.
22
5.10
Outstanding Capital Commitments.
Except for Neo Canyons commitments under the
Authorizations for Expenditures (
AFEs
) for the currently drilling Wells and the matters which are
set forth in
Schedule 5.10
, there are no pending AFEs and there are no outstanding AFEs or
other commitments to make capital expenditures, which are binding on Neo Canyon or the Neo Canyon
Oil and Gas Properties and which Neo Canyon reasonably anticipates will individually (per AFE)
require expenditures as of such date in excess of $150,000.00. However, the Neo Canyon Oil and Gas
Properties are subject to active and ongoing exploration and Neo Canyon anticipates that there
could be further well proposals at any time.
5.11
Compliance with Laws.
Neo Canyon holds all material Permits necessary for the
lawful conduct of its business and is in compliance in all material respects, with all Laws and
Orders applicable to its business and has filed with the proper authorities all statements and
reports required by the Laws and Orders to which Neo Canyon or any of its properties or operations
are subject. No claim has been made by any Governmental Authority (and, to Neo Canyons Knowledge,
no such claim is anticipated) to the effect that the business conducted by Neo Canyon fails to
comply, in any respect, with any Law.
5.12
Forward Sales.
Except as disclosed in
Schedule 5.12
, Neo Canyon is not
obligated by virtue of a take or pay payment, advance payment or other similar payment (other than
royalties, overriding royalties and similar arrangements reflected on
Exhibit C
), to
deliver Hydrocarbons, or proceeds from the sale thereof, attributable to the Leases at some future
time without receiving payment therefor at or after the time of delivery.
5.13
Properties.
Except as set forth in
Schedule 5.13
and except for
Hydrocarbon sales contracts with a term not greater than thirty (30) days, no Hydrocarbons produced
from the Neo Canyon Oil and Gas Properties are subject to a sales contract or other agreement
relating to the marketing of Hydrocarbons, and no person has any call upon, option to purchase or
similar rights with respect to such Neo Canyon Oil and Gas Properties or the rights therefrom,
except for third party operator rights under operating agreements covering the Neo Canyon Oil and
Gas Properties.
5.14
Consents and Preferential Purchase Rights.
Except as set forth in
Schedule
5.14
, none of the Leases are subject to any preferential rights to purchase or restrictions on
assignment or required third-party consents to assignment which may be applicable to the
transactions contemplated by this Contribution Agreement, except for governmental consents and
approvals of assignments that are customarily obtained after Closing.
5.15
Contracts.
Neither Neo Canyon nor to Neo Canyons Knowledge, any other party is
in default under any contract except for such defaults as would not have an ARI Material Adverse
Effect. There are no contracts with Affiliates of Neo Canyon which will be binding on the Neo
Canyon Oil and Gas Properties after Closing. Except as set forth in
Schedule 5.15
, none of
the contracts consist of, nor are the Neo Canyon Oil and Gas Properties subject to any, Hedging
Transaction which will be binding on ARI.
5.16
Intentionally Omitted.
23
5.17
Intentionally Omitted.
5.18
Intellectual Property.
Except as disclosed on
Schedule 5.18
, Neo Canyon
does not own or use any Intellectual Property in the ownership and operation of the Neo Canyon Oil
and Gas Properties. Neo Canyon has received no written notice, and has no knowledge of, any
infringements or unauthorized or unlawful use of any Intellectual Property by Neo Canyon or any
allegation that Neo Canyons use of such Intellectual Property has infringed similar properties of
others.
5.19
Accredited Investor
. Neo Canyon is an accredited investor within the meaning
of Regulation D, Rule 501(a), promulgated by the Commission.
5.20
Restricted Securities
. Neo Canyon understands that the shares of ARI Common
Stock will not have been registered pursuant to the Securities Act or any applicable state
securities laws, that the shares of ARI Common Stock will be characterized as restricted
securities under federal securities laws, and that under such laws and applicable regulations the
shares of ARI Common Stock cannot be sold or otherwise disposed of without registration under the
Securities Act or an exemption therefrom. In this connection, Neo Canyon represents that it is
familiar with Rule 144 promulgated under the Securities Act, as currently in effect, and
understands the resale limitations imposed thereby and by the Securities Act. A legend indicating
that the shares of ARI Common Stock have not been registered under applicable federal and state
securities laws and referring to the restrictions on transferability and sale of the ARI Common
Stock pursuant to this Contribution Agreement or otherwise may be placed on any certificate(s) or
other document delivered to Neo Canyon or any substitute therefor and any transfer agent of ARI may
be instructed to require compliance therewith.
5.21
Investment Intent.
The ARI Common Stock is being acquired for Neo Canyons own
investment portfolio and account (and not on behalf of, and without the participation of, any other
Person) with the intent of holding the ARI Common Stock for investment and without the intent of
participating, directly or indirectly, in a distribution of the ARI Common Stock and not with a
view to, or for resale in connection with, any distribution of the ARI Common Stock in violation of
applicable securities laws or any portion thereof in violation of applicable securities laws. As
of the Closing Date, Neo Canyon does not have plans to transfer any of the ARI Common Stock on a
specified date or to a specified person, other than as contemplated hereby.
ARTICLE VI.
REPRESENTATIONS AND WARRANTIES OF THE AOG STOCKHOLDERS, LUBAR AND YORKTOWN VII
Each of the AOG Stockholders, Lubar and Yorktown VII severally and not jointly represents and
warrants to ARI and Neo Canyon that the statements contained in this
Article VI
are correct
and complete as of the date hereof.
6.1
Organization and Good Standing
. Each of such AOG Stockholders, Lubar and Yorktown
VII is duly organized, validly existing and in good standing under the Laws of the jurisdiction in
which it is organized and has all requisite power and authority to execute, deliver
24
and perform its
obligations under this Contribution Agreement and to consummate the transactions contemplated
hereby.
6.2
Authority and Enforceability
. The execution and delivery by each of such AOG
Stockholders, Lubar and Yorktown VII of this Contribution Agreement and the consummation of the
transactions contemplated hereby (if such AOG Stockholder is not a natural Person) have been duly
and validly authorized by all necessary corporate or other action and no other corporate or other
proceedings are necessary to consummate the transactions contemplated hereby. This Contribution
Agreement has been duly and validly executed and delivered and constitutes a valid and binding
obligation of each of such AOG Stockholders, Lubar and Yorktown VII, enforceable against each of
such AOG Stockholders, Lubar and Yorktown VII in accordance with its terms, except as such
enforceability may be limited by bankruptcy,
insolvency, reorganization and similar Laws affecting creditors generally and by the
availability of equitable remedies.
6.3
No Conflict; Required Filings and Consents
. The execution and delivery of this
Contribution Agreement by each of such AOG Stockholders, Lubar and Yorktown VII do not, and the
performance by each of such AOG Stockholders, Lubar and Yorktown VII of the transactions
contemplated hereby or thereby will not violate, conflict with, require any consent under or result
in a violation or breach of, or constitute a default (with or without due notice or lapse of time
or both) under, or give any party the right to terminate or accelerate any obligation, or give rise
to the creation of any Lien upon any property or asset of AOG under, any of the terms, conditions,
or provisions of any organizational document, contract or other instrument or obligation to which
each of such AOG Stockholders, Lubar and Yorktown VII is a party or by which it may be bound, or
violate any Law or Order of any Governmental Authority binding upon each of such AOG Stockholders,
Lubar and Yorktown VII. No consent of or registration, declaration, or filing with any
Governmental Authority is required by or with respect to each of such AOG Stockholders, Lubar and
Yorktown VII in connection with the execution and delivery of this Contribution Agreement by each
of such AOG Stockholders, Lubar and Yorktown VII or the consummation of the transactions
contemplated hereby.
6.4
Ownership
. Such AOG Stockholder is the holder of record of and owns beneficially
the AOG Common Stock identified as being owned by such AOG Stockholder in
Section 2.1
and
to be acquired by ARI in accordance with
Section 2.1
, and, as of the Closing Date, such AOG
Stockholder will be the holder of record and will own beneficially the AOG Common Stock, free and
clear of all Liens. On the Closing Date, ARI will receive good and valid title to the AOG Common
Stock owned by such AOG Stockholder, free and clear of all Liens.
6.5
Accredited Investor
. Each of such AOG Stockholders, Lubar and Yorktown VII is an
accredited investor within the meaning of Regulation D, Rule 501(a), promulgated by the
Commission.
6.6
Restricted Securities
. Each of such AOG Stockholders, Lubar and Yorktown VII
understands that the shares of ARI Common Stock will not have been registered pursuant to the
Securities Act or any applicable state securities laws, that the shares of ARI Common Stock will be
characterized as restricted securities under federal securities laws, and that under such laws
25
and applicable regulations the shares of ARI Common Stock cannot be sold or otherwise disposed of
without registration under the Securities Act or an exemption therefrom. In this connection, each
of such AOG Stockholders, Lubar and Yorktown VII represents that it is familiar with Rule 144
promulgated under the Securities Act, as currently in effect, and understands the resale
limitations imposed thereby and by the Securities Act. A legend indicating that the shares of ARI
Common Stock have not been registered under applicable federal and state securities laws and
referring to the restrictions on transferability and sale of the ARI Common Stock pursuant to this
Contribution Agreement or otherwise may be placed on any certificate(s) or other document delivered
to each of such AOG Stockholders, Lubar and Yorktown VII or any substitute therefor and any
transfer agent of ARI may be instructed to require compliance therewith.
6.7
Investment Intent
. The ARI Common Stock is being acquired for the own investment
portfolio and account (and not on behalf of, and without the participation of, any other Person) of
each of such AOG Stockholders, Lubar and Yorktown VII with the intent of holding the ARI Common
Stock for investment and without the intent of participating, directly or indirectly, in a
distribution of the ARI Common Stock and not with a view to, or for resale in connection with, any
distribution of the ARI Common Stock in violation of applicable securities laws or any portion
thereof in violation of applicable securities laws. As of the Closing Date, none of each AOG
Stockholder, Lubar or Yorktown VII has plans to transfer any of the ARI Common Stock on a specified
date or to a specified person, other than in connection with the ARI Initial Public Offering.
ARTICLE VII.
REPRESENTATIONS AND WARRANTIES OF ARI
ARI represents and warrants to AOG, the AOG Stockholders, Lubar, Yorktown VII and Neo Canyon
that the statements contained in this
Article VII
are correct and complete as of the date
hereof (it being recognized that each such representation and warranty with respect to ARIs
operations and the ARI Oil and Gas Properties shall be deemed to refer to ARI and each of its
Subsidiaries, taken as a whole).
7.1
Organization and Power.
Each of ARI and its Subsidiaries is duly incorporated or
formed (as the case may be), validly existing and in good standing (as applicable) under the Laws
of its respective jurisdiction of incorporation or formation, and is qualified and in good standing
to transact business in each jurisdiction in which such qualification is required by Law, except
where the failure to be so qualified would not have an ARI Material Adverse Effect. ARI has all
requisite corporate power and authority to execute, deliver and perform its obligations under this
Contribution Agreement and to consummate the transactions contemplated hereby. ARI has heretofore
delivered or made available to the AOG Stockholders and Neo Canyon complete and correct copies of
(a) its certificate of incorporation and bylaws, each as amended to date, and (b) its Subsidiaries
respective certificates of incorporation and bylaws, or other comparable organizational documents,
each as amended to date.
7.2
Authorizations; Execution and Validity.
The execution and delivery of this
Contribution Agreement by ARI, the performance of this Contribution Agreement by ARI and
26
the
consummation by ARI of the transactions contemplated hereby and thereby to be consummated by it,
have been duly authorized by all necessary corporate action and, except for the approval of the New
ARI Charter as provided herein, no other corporate action on the part of ARI is necessary with
respect thereto. This Contribution Agreement has been duly executed and delivered by ARI and, when
duly and validly executed and delivered, will constitute a valid and binding obligation of ARI and
is enforceable against ARI in accordance with its terms, except as such enforceability may be
limited by bankruptcy, insolvency, reorganization and similar Laws affecting creditors generally
and by the availability of equitable remedies.
7.3
Capitalization.
(a) As of the date hereof, the authorized capital stock of ARI consists solely of 4,000,000
shares of ARI Common Stock and 1,000,000 shares of ARI Preferred Stock. As of the date hereof,
there are an aggregate of 2,852,085 shares of Common Stock issued and outstanding, all of which
shares are owned of record and beneficially, by the ARI Stockholders with each ARI Stockholder
owning the number of shares set forth on
Schedule 7.3(a)
hereto, and have been duly
authorized and validly issued, and are fully-paid and non-assessable. No shares of ARI Preferred
Stock are issued and outstanding. As of the date hereof, ARI had outstanding options which had
been issued to the individuals and entities listed on
Schedule 7.3(a)
totaling 115,385
shares of ARI Common Stock. As of the date hereof, the issued and outstanding amount of ARI Common
Stock on a fully diluted basis is 2,967,470 shares. Except as contemplated by the ARI Registration
Statement, the Lubar Note, the Yorktown Note, future issuances of equity or convertible debt in
connection with financing transactions or acquisitions that the ARI Board reasonably determines to
be in the best interests of ARI and its stockholders, and with respect to options, warrants, rights
or other equity based awards issued as part of reasonable compensation plans approved by the ARI
Board, as of the Closing Date, there shall be no outstanding options, subscriptions, warrants,
calls, commitments, pre-emptive rights or other rights obligating ARI to issue or sell any shares
of its capital stock or any securities convertible into or exercisable for any shares of its
capital stock, or otherwise requiring ARI to give any Person the right to receive any benefits or
rights similar to any rights enjoyed by or accruing to the holders of shares of capital stock of
ARI or any rights to participate in the equity or net income of ARI. All of the issued shares of
ARIs capital stock were issued, and to the extent purchased or transferred, have been so purchased
or transferred, in compliance with all applicable Laws, including federal and state securities
Laws, and any preemptive rights and any other statutory or contractual rights of any ARI
Stockholder.
(b) ARI has no Subsidiaries other than those set forth on
Schedule 7.3(b)
. ARI,
directly or indirectly, owns all capital of and other equity interests in its Subsidiaries, and
there are no outstanding options, subscriptions, warrants, calls, commitments, pre-emptive rights
or other rights in favor of any Person other than ARI or other ARI Subsidiaries obligating ARI or
any of its Subsidiaries to issue or sell any shares or other equity interests of any of ARIs
Subsidiaries or any securities convertible into or exercisable for any shares or other equity
interests of any such Subsidiary, or otherwise requiring ARI or any of its Subsidiaries to give any
Person (other than ARI or any of its Subsidiaries) the right to receive any benefits or rights
similar to any rights enjoyed by or accruing to the holders of shares or other equity interests of
any such Subsidiary or any rights to participate in the equity or net income of any such
Subsidiary. ARI does not own, directly or indirectly, any capital of or other equity interest in
or
27
has any other investment in any other Person other than its Subsidiaries. Except for the
Stockholders Agreement and as otherwise set forth on
Schedule 7.3(c)
, there are no
stockholders agreements, voting trusts or other agreements or understandings between or among ARI
Stockholders or to which ARI is a party or by which it is bound with respect to the transfer or
voting of any capital stock of ARI, none of which, except as disclosed in
Schedule 7.3(c)
,
shall be in effect following the Closing.
7.4
Financial Statements; Other Financial Data.
Attached hereto on
Schedule
7.4
are correct and complete copies of the audited consolidated balance sheet of ARI and its
Subsidiaries as of December 31, 2006 with the related consolidated statements of operations,
changes in stockholders equity, and cash flows for the year then ended (the
ARI Audited Financial
Statements
) and the unaudited consolidated balance sheet of ARI and its Subsidiaries as of
March 31, 2007 with the related unaudited consolidated statements of operations, changes in
stockholders equity, and cash flows for the quarter then ended (the
ARI Unaudited Financial
Statements
and, together with the ARI Audited Financial Statements, the
ARI Financial
Statements
). The ARI Financial Statements present fairly in all material respects the financial
position of ARI as of the dates indicated, and the results of its operations for the respective
periods indicated. The ARI Audited Financial Statements are in conformity with GAAP, consistently
applied. The ARI Unaudited Financial Statements are unaudited and, therefore, are subject to
normal recurring year-end adjustments and the absence of footnotes.
7.5
Consents.
Neither the execution and delivery by ARI of this Contribution
Agreement nor the consummation or performance by ARI of the transactions contemplated by this
Contribution Agreement to be consummated or performed by it will require prior to the Closing (on
the part of ARI) any consent from, authorization or approval or other action by, notice to or
declaration, filing or a registration with, any Governmental Authority or any other third party,
except, if required, to comply with the HSR Act or as specified in
Schedule 7.5
.
7.6
No Defaults or Conflicts.
Neither the execution and delivery by ARI of this
Contribution Agreement nor the consummation or performance by ARI of the transactions contemplated
by this Contribution Agreement to be consummated or performed by it (i) results or will result in
any violation of the certificate of incorporation or bylaws of ARI or other organizational or
governing documents of ARI or any of its Subsidiaries; or (ii) subject to obtaining the required
consent, if any, from ARIs Senior Lender, violates or conflicts with, or constitutes a breach of
any of the terms or provisions of or a default under, or results in the creation or imposition of
any Lien upon any property or asset of ARI, the trigger of any charge, payment or requirement of
consent, or the acceleration or increase of the maturity of any payment date under: (A) any
Material Contract to which ARI is a party or (B) any applicable Law or Order to which ARI or any of
its respective properties is subject, other than, in each case, where such failure, conflict or
breach would not have an ARI Material Adverse Effect.
7.7
Agreements, Contracts and Commitments.
ARI has listed in
Schedule 7.7
all
Material Contracts to which it is a party (true and correct copies of each such document have been
previously delivered or made available to the AOG Stockholders and Neo Canyon). Except as set
forth in
Schedule 7.7
, ARI has not breached, nor to ARIs Knowledge is there any claim or
any legal basis for a claim that ARI or any third party has breached, any of the terms or
conditions of any Material Contract if any such breach, whether considered individually or in the
28
aggregate, could result in the imposition of damages or the loss of benefits in an amount or of a
kind that would have an ARI Material Adverse Effect to ARI and its Subsidiaries taken as a whole.
7.8
Litigation.
Schedule 7.8
lists all Legal Proceedings pending or, to ARIs
Knowledge, threatened against or affecting ARI or any of its assets. Except as disclosed on
Schedule 7.8
, ARI is not subject to any Order. There are no Legal Proceedings pending
against or, to ARIs Knowledge, threatened in writing against, ARI that questions the validity or
legality of any of this Contribution Agreement or any action taken or to be taken by ARI in
connection herewith or therewith.
7.9
ERISA Compliance; Labor.
(a) Except as set forth on
Schedule 7.9
, neither ARI nor any other Aggregated Group
sponsors, maintains or contributes to any Employee Benefit Plan.
(b) No labor associations, organizations, or unions have been certified to represent any
employee of ARI, and no collective bargaining agreement or other labor union contract has been
requested by any employee or group of employees of ARI, and no discussions or negotiations with
respect to any such agreement or contract have occurred.
(c) ARI and its Subsidiaries are in material compliance with all Laws, rules, regulations and
Orders relating to the employment of labor, including all such Laws, rules, regulations and Orders
relating to wages, hours, collective bargaining, discrimination, civil rights, safety and health,
workers compensation and the collection and payment of withholding or Social Security Taxes and
similar Taxes.
7.10
Taxes.
Except as disclosed on
Schedule 7.10
:
(a) All material Tax Returns required to be filed on or before the Closing Date by or on
behalf of ARI have been or will be filed within the time prescribed by Law (including extensions of
time permitted by Law) and such Tax Returns are true, correct, complete and accurate in all
material respects and reflect accurately in all material respects all liability for Taxes of ARI or
any of its Subsidiaries.
(b) ARI has paid, on a timely basis, all material Taxes of ARI and of any of its Subsidiaries
that are due on or before December 31, 2006, and will have paid all material Taxes of ARI and of
any of its Subsidiaries that are due on or before the Closing Date.
(c) The provision for Taxes and other accrued Tax liabilities reflected in the Financial
Statements are sufficient to cover all material liabilities for Taxes in respect of Tax Periods
ending at or prior to the relevant Financial Statement date.
(d) There are no Liens for Taxes upon any of the properties or assets of ARI or of any of its
Subsidiaries (except for Permitted Liens).
(e) There are no pending Orders, audits, actions, proceedings, investigations, disputes or
claims instigated by any Governmental Authority with respect to any Taxes payable
29
by or asserted
against ARI or any of its Subsidiaries. Neither ARI nor any of its Subsidiaries has received
notice from any taxing authority of its intent to examine or audit any of its Tax Returns.
(f) Neither ARI nor any of its Subsidiaries is subject to Tax or has done business in any
country other than the United States.
(g) All Taxes required to be withheld, collected or deposited by ARI or any of its
Subsidiaries (including, without limitation, amounts required to be withheld, collected or
deposited with respect to amounts paid or owing to any employee, creditor, independent contractor
or other Person) have been timely withheld, collected or deposited and, to the extent required,
have been timely paid to the relevant taxing authority.
(h) There are no outstanding agreements or waivers that would extend the statutory period in
which a taxing authority may assess or collect a Tax against ARI or any of its Subsidiaries.
7.11
Brokers.
Other than the commission payable pursuant to the Underwriting
Agreement, ARI has not paid or become obligated to pay any fee or commission to any broker, finder
or intermediary in connection with the transactions contemplated hereby for which ARI, AOG or Neo
Canyon shall have liability following the Closing.
7.12
Absence of Certain Changes or Events.
Except as set forth on
Schedule
7.12
or as disclosed in the ARI Audited Financial Statements or the ARI Unaudited Financial
Statements, since March 31, 2007, there has not been any transaction or occurrence in which ARI
has:
(a) suffered any Material Adverse Effect;
(b) declared, set aside or paid any dividend or other distribution (whether in cash, stock or
property) with respect to any of its outstanding capital stock, or made any redemption, purchase or
other acquisition of any of its equity securities;
(c) cancelled any debts or waived any receivables, claims or rights in excess of $2,500,000
individually;
(d) suffered any uninsured casualty loss or damage in excess of $2,500,000 individually;
(e) amended any term of any equity security of ARI other than as contemplated by this
Contribution Agreement; or
(f) made any change in its accounting methods, principles or practices.
7.13
Compliance with Laws.
ARI holds all material Permits necessary for the lawful
conduct of its business and is in compliance in all material respects, with all Laws and Orders
applicable to its business and has filed with the proper authorities all statements and reports
required by the Laws and Orders to which ARI or any of its properties or operations are subject.
No claim has been made by any Governmental Authority (and, to ARIs Knowledge, no such
30
claim is
anticipated) to the effect that the business conducted by ARI fails to comply, in any respect, with
any Law.
7.14
Transactions with Related Parties.
Except for the Stockholders Agreement,
transactions with any of ARIs Subsidiaries and as otherwise set forth on
Schedule 7.14
:
(a) No Affiliate has entered into, or has had any direct or indirect financial interest in,
any ARI Material Contract, transaction or business dealings involving ARI;
(b) No Affiliate owns or has any interest in, directly or indirectly, in whole or in part, any
tangible or intangible property used in the conduct of the business of ARI;
(c) Other than amounts owed to ARI pursuant to any intercompany debts, joint interest billing
and general and administrative allocations, or expense advance reimbursements in the ordinary
course of business, no Affiliate owes any money to, nor is any such Affiliate owed any money by,
ARI other than as set forth in this Contribution Agreement; and
(d) ARI has not, directly or indirectly, guaranteed or assumed any indebtedness for borrowed
money or otherwise for the benefit of any Affiliate of ARI.
7.15
Agents.
Except as set forth on
Schedule 7.15
, ARI has not designated or
appointed any person or other entity to act for it or on its behalf pursuant to any power of
attorney or any agency which is presently in effect (other than such of ARIs directors, officers
and employees to whom ARI has given the authority to act for ARI in the ordinary course of its
business) or shall continue after the Closing Date.
7.16
Books and Records.
The minute books and records of ARI are current as of the
date hereof (and shall be current as of the Closing) with respect to all undertakings and
authorizations, and contain a true, complete and correct record of all actions taken at all
meetings and by all written consents in lieu of meetings of the ARI Board, or any committees
thereof, and the ARI Stockholders. The stock ledger and related stock transfer records of ARI
contain a true, complete and correct record of the original issuance, transfer and other
capitalization matters of the capital stock of ARI. The accounting, financial reporting, tax and
business books and records of ARI accurately and fairly reflect in all material respects the
business and condition of ARI and the transactions and the assets and liabilities of ARI with
respect thereto. Without limiting the generality of the foregoing, ARI has not engaged in any
transaction with respect to its business or operations, maintained any bank account therefor or
used any funds of ARI in the conduct thereof except for transactions, bank accounts and funds that
have been and are reflected in the normally maintained books and records of the business.
7.17
Information Furnished.
ARI has made available to AOG and Neo Canyon and their
respective directors, officers, employees, counsel, representatives, financing sources, customers,
creditors, accountants and auditors, true and correct copies of all agreements, documents, and
other items listed on the Schedules to this Contribution Agreement and all books and records of
ARI.
31
7.18
Directors and Officers.
Schedule 7.18
lists all of the directors and
officers of ARI as of the Closing Date.
7.19
Bank Accounts.
Attached hereto as
Schedule 7.19
is a list of all banks
or other financial institutions with which ARI has an account, showing the type and account number
of each such account.
7.20
Owned Real Property.
Other than the ARI Oil and Gas Properties, ARI does not own
any real property.
7.21
Leased Real Property.
Other than the ARI Oil and Gas Properties,
Schedule
7.21
contains a complete and correct list of all Real Property Leases. ARI has provided or
made available to the AOG Stockholders and Neo Canyon correct and complete copies of the Real
Property Leases. Except as disclosed in
Schedule 7.21
, (i) each of the Real Property
Leases is in
full force and effect, and, to ARIs Knowledge, is enforceable against the landlord which is
party thereto in accordance with its terms (except as such enforceability may be limited by
bankruptcy, insolvency, reorganization and similar laws affecting creditors generally and by the
availability of equitable remedies), (ii) there are no subleases under the Real Property Leases and
none of the Real Property Leases has been assigned (other than collateral assignments to ARIs
Senior Lender), (iii) no notices of default or notices of termination have been received by ARI
with respect to the Real Property Leases which have not been withdrawn or canceled and (iv) ARI is
not, and to ARIs Knowledge, no other party is, in default under any Real Property Lease. There is
no ARI Knowledge of, nor has there been receipt of any written notice of a proceeding in eminent
domain or other similar proceeding affecting property listed on
Schedule 7.21
.
7.22
Insurance.
Schedule 7.22
contains a true and complete list of all
insurance policies, directors and officers liability policies, and formal self-insurance programs,
and other forms of insurance and all fidelity bonds held by or applicable to ARI and its owned or
leased properties.
Schedule 7.22
describes (a) whether each insurance policy listed on
Schedule 7.22
is occurrence-based or claims made based and (b) each pending claim
thereunder for more than $1,000,000 per claim and a history of all such claims made against any
such insurance policy of ARI for the past three (3) years. All insurance policies listed on
Schedule 7.22
have been made available to the AOG Stockholders and Neo Canyon and are
subject to the deductibles or retentions referenced on
Schedule 7.22
. ARI maintains
insurance for its benefit, in coverages and amounts to be customary and adequate in the oil and gas
industry. ARI is not in default with respect to any provision in any current policy maintained for
its benefit, and all such insurance is in full force and effect. ARI has not received, nor is
there any ARI Knowledge of, any notice of cancellation or nonrenewal of any such insurance policy.
ARI has not failed to give any notice or present any claim for more than $1,000,000 under any of
the policies for the benefit of ARI in due and timely fashion. ARI has not been refused any
insurance with respect to its assets, properties or businesses, nor has any such coverage been
materially limited by any insurance carrier to which ARI has applied for any such insurance or with
which ARI has carried insurance during the past three (3) years. Other than as described on
Schedule 7.22
, no further payments of premiums will be due following the Closing by ARI
with respect to insurance coverages prior to the Closing. Neither this Contribution Agreement nor
any of the transactions contemplated by this Contribution Agreement to occur at the Closing will
adversely affect ARIs coverage under the terms of the insurance policies with respect to periods
prior to the Closing.
32
7.23
Title to Oil and Gas Properties.
ARI has Defensible Title to all ARI Oil and Gas
Properties. All proceeds from the sale of ARIs share of the Hydrocarbons being produced from the
ARI Oil and Gas Properties are currently being paid in full to ARI by the purchasers thereof on a
timely basis, and none of such proceeds are currently being held in suspense by such purchaser or
any other party, except as set forth in
Schedule 7.23
.
7.24
Environmental Matters.
Except as set forth in
Schedule 7.24
:
(a) to ARIs Knowledge, it has conducted its business and operated its assets, and is
conducting its business and operating its assets, and the condition of all facilities and
properties (including off site storage or disposal of any Hazardous Materials from such facilities
or properties) currently or formerly owned, leased or operated by ARI is, in material compliance
with all Environmental Laws;
(b) ARI has not been notified by any Governmental Authority or other third party that any of
the operations or assets of ARI is the subject of any investigation or inquiry by any Governmental
Authority or other third party evaluating whether any material remedial action is needed to respond
to a release or threatened release of any Hazardous Material or to the improper storage or disposal
(including storage or disposal at offsite locations) of any Hazardous Material where such
investigation or inquiry has not been fully resolved and satisfied as of the date hereof;
(c) neither ARI nor, to ARIs Knowledge, any other Person has filed any notice under any
federal, state or local Law indicating that (i) ARI is responsible for the improper release into
the environment, or the improper storage or disposal, of any Hazardous Material, or (ii) any
Hazardous Material is improperly stored or disposed of upon any property of ARI;
(d) to ARIs Knowledge, it does not have any material liability (contingent or otherwise) in
connection with (i) the release or threatened release into the environment at, beneath or on any
property now or previously owned or leased by ARI, or (ii) the storage or disposal of any Hazardous
Material;
(e) ARI has not received any claim, complaint, notice, inquiry or request for information
involving any matter which remains unresolved as of the date hereof with respect to any alleged
violation of any Environmental Law or regarding current or potential liability under any
Environmental Law or any personal injury, property damage or natural resource damage claim relating
to operations or conditions of any facilities or property (including off site storage or disposal
or release of any Hazardous Material from such facilities or property) currently or formerly owned,
leased or operated by ARI;
(f) to ARIs Knowledge, no property now or previously owned, leased or operated by ARI is
listed on the National Priorities List pursuant to CERCLA or on the CERCLIS or on any other federal
or state list as sites requiring investigation or cleanup;
(g) to ARIs Knowledge, it is not directly transporting, has not directly transported, is not
directly arranging for the transportation of, or has not directly transported, any Hazardous
Material to any location which is listed on the National Priorities List pursuant to
33
CERCLA, on the
CERCLIS, or on any similar federal or state list or which is the subject of federal, state or local
enforcement actions or other investigations that may lead to material claims against ARI for
remedial work, damage to natural resources or personal injury, including claims under CERCLA;
(h) except for the draining and backfilling of pits associated with drilling activities in the
ordinary course, there are no sites, locations or operations at which ARI is obligated to
undertake, is currently undertaking, or has completed, any remedial or response action relating to
any disposal or release, as required by Environmental Laws; and
(i) ARI does not own or operate any underground storage tanks or solid waste disposal
facilities.
7.25
Patents, Trademarks and Similar Rights.
ARI owns or is properly licensed to use
or otherwise has rights to use all Intellectual Property (specifically including any seismic
license or Permit) material to the operations of the business of ARI as currently conducted. To
ARIs
Knowledge, except as set forth on
Schedule 7.25
, (i) the entry into this Contribution
Agreement and the transactions contemplated hereby will not have any effect on any contracts
related to Intellectual Property, and (ii) neither ARI nor, to ARIs Knowledge, any other party, is
in breach of or default under any Intellectual Property license or any other contract or legal
requirement relating to the Intellectual Property, in each such case.
7.26
Plugging and Abandonment.
As to Wells operated by ARI, there are no Wells that:
(i) ARI is currently obligated by Law or contract to plug and abandon; or (ii) have been plugged
and abandoned in a manner that does not comply in all material respects with Law, in each such
case, where the obligation or failure to comply would reasonably be expected to have an ARI
Material Adverse Effect.
7.27
Additional Drilling Obligations.
To ARIs Knowledge, except as set forth on
Schedule 7.27
, there are no current obligations or assessments of ARI or any of its
Subsidiaries (other than implied obligations under leases to which ARI is a party concerning
protection from drainage and further development that is customary in the oil and gas industry)
that require the drilling of additional Wells or other material development operations (including
re-entry of existing Wells) in order to earn or to continue to hold all or any portion of the Oil
and Gas Properties, where the obligation or assessment would, individually or in the aggregate,
reasonably be expected to have an ARI Material Adverse Effect.
7.28
Gas Imbalances.
Except as set forth in
Schedule 7.28
, ARI has no gas
production imbalances attributable to the ARI Oil and Gas Properties.
ARTICLE VIII.
COVENANTS
8.1
Ordinary Course of Business
. Except as otherwise contemplated herein or in
connection with the ARI Initial Public Offering, between the date of this Contribution Agreement
and the earlier to occur of the Closing Date or the termination of this Contribution Agreement,
ARI, AOG and Neo Canyon, as applicable, will carry on their respective businesses
34
diligently and in
the ordinary and usual course and consistent with past practice, and, without limiting the
generality of the foregoing, and ARI, AOG and Neo Canyon will use, and Neo Canyon GP will cause Neo
Canyon to use, commercially reasonable efforts to preserve their respective business organizations
intact, keep available the services of their respective present executive officers and employees
and preserve their respective present relationships with persons having business dealings with it.
8.2
AOG Restricted Activities and Transactions
. Except as otherwise contemplated
herein or in connection with the ARI Initial Public Offering, as set forth on
Schedule 8.2
,
or as otherwise consented to in writing by ARI, AOG, Neo Canyon, Lubar and Yorktown VII, between
the date of this Contribution Agreement and the earlier to occur of the Closing Date or the
termination of this Contribution Agreement, (i) the AOG Stockholders shall not sell, transfer or
otherwise deliver their common stock in AOG, and (ii) AOG will not:
(a) except (i) as contemplated by the Lubar Note and the Yorktown Note, (ii) subject to
Section 10.1(d)
, for future issuances of equity or convertible debt in connection with
financing transactions or acquisitions that the ARI Board reasonably determines to be in the best
interests of ARI and its stockholders, or (iii) for options, warrants, rights, or other
equity-based awards issued as part of reasonable compensation plans approved by the ARI Board or
the AOG Board, issue or commit to issue any of its capital stock or other ownership or equity
interests;
(b) except (i) as contemplated by the Lubar Note and the Yorktown Note, (ii) subject to
Section 10.1(d)
, for future issuances of equity or convertible debt in connection with
financing transactions or acquisitions that the ARI Board reasonably determines to be in the best
interests of ARI and its stockholders, or (iii) for options, warrants, rights, or other
equity-based awards issued as part of reasonable compensation plans approved by the ARI Board or
the AOG Board, grant or commit to grant any options, warrants, convertible securities or other
rights to subscribe for, purchase or otherwise acquire any shares of its capital stock or other
ownership or equity interests;
(c) declare, set aside, or pay any dividend or distribution or make any other payment with
respect to its capital stock or other ownership interests except in the ordinary and usual course
and consistent with past practice;
(d) directly or indirectly redeem, purchase or otherwise acquire or commit to acquire any of
its capital stock or other ownership or equity interests;
(e) effect a split or reclassification of any of its capital stock or a recapitalization or
other reorganization;
(f) amend or otherwise alter its certificate of incorporation, bylaws, limited liability
agreement or limited partnership agreement or other governing instruments;
(g) enter into or make any change in any of its Employee Benefit Plans or grant any increase
in compensation (other than increases in compensation in the ordinary course of business for field
and office personnel who are not managers or executives), or provide any special severance
arrangement involving any of its employees, officers or directors;
35
(h) except in the ordinary course of business or as otherwise permitted under this
Contribution Agreement and except for budgeted capital expenditures, enter into or agree to enter
into any agreement or transaction involving the incurrence of an obligation to pay an amount in
excess of an aggregate of $30,000,000;
(i) create, assume or permit to exist any Lien on any of its assets, tangible or intangible,
except (i) as permitted under its existing credit facilities with banks and any renewals,
modifications or rearrangements thereof on terms and conditions not materially less favorable to
the respective borrower or (ii) in the ordinary course of business consistent with past practice;
(j) except as in the ordinary and usual course of business and consistent with past practice
or as otherwise contemplated or permitted herein, (i) cancel or agree to cancel any debts or
claims, (ii) lease, sublease, sell or transfer, agree to sublease, sell or transfer, or grant or
agree to grant any preferential rights to lease or acquire, any of its assets, property or rights
having a
fair market value in excess of $2,000,000 or (iii) make or permit any material amendment or
termination of any Material Contract, agreement, license or other right to which it is a party;
(k) settle any threatened or pending litigation that is not fully covered by insurance other
than for immaterial consideration or for an amount less than that reserved as of the date hereof
for such litigation on its books and records; or
(l) commit itself to do any of the foregoing.
8.3
Neo Canyon Restricted Activities and Transactions
. Between the date of this
Contribution Agreement and the earlier to occur of the Closing Date or the termination of this
Agreement, Neo Canyon will and Neo Canyon GP will cause Neo Canyon to (except as consented to in
writing by ARI, AOG, Lubar and Yorktown VII or otherwise permitted under this Agreement):
(a) not terminate, amend or extend any material contracts affecting the Neo Canyon Oil and Gas
Properties, or enter into or commit to enter into any new material contract relating to the Neo
Canyon Oil and Gas Properties, or settle, compromise or waive any right relating to the Neo Canyon
Oil and Gas Properties,
(b) maintain insurance coverage on the Neo Canyon Oil and Gas Properties in the amounts and of
the types presently in force,
(c) use commercially reasonable efforts to cause the operator to maintain in full force and
effect the Leases and other Neo Canyon Oil and Gas Properties, and pay all costs and expenses and
perform all material obligations of the owner of the Neo Canyon Oil and Gas Properties promptly
when due,
(d) use commercially reasonable efforts to cause the operator to maintain all Permits,
36
(e) not transfer, sell, hypothecate, encumber or otherwise dispose of any Neo Canyon Oil and
Gas Properties except for sales and dispositions of Hydrocarbons made in the ordinary course of
business consistent with past practices,
(f) not grant or create any preferential right to purchase, right of first opportunity or
other transfer restriction or requirement with respect to the Neo Canyon Oil and Gas Properties
except in connection with the renewal or extension of Neo Canyon Oil and Gas Properties after the
Closing Date if granting or creating such right or requirement is a condition of such renewal or
extension,
(g) use commercially reasonable efforts to cause the operator to maintain the equipment in at
least as good a condition as it is on the date hereof, ordinary wear and tear excepted, and
(h) not make any change in any method of accounting or accounting practice or policy with
respect to the Neo Canyon Oil and Gas Properties.
8.4
HSR and Other Regulatory Matters.
Each of the parties hereto agrees to make all
necessary filings on a timely basis with respect to the HSR Act, and other applicable laws and will
use its commercially reasonable efforts to obtain any other regulatory approvals which may be
required to consummate the transactions contemplated herein. Notwithstanding anything in this
Contribution Agreement to the contrary, if any party hereto or any Affiliate thereof is required to
make a filing under any such acts in connection with the transactions contemplated by this
Contribution Agreement, the filing fees of such Person shall be borne by the party whose equity
ownership gave rise to such filing obligation.
8.5
Commercially Reasonable Efforts
. Upon the terms and subject to the conditions
hereof, each of the parties hereto agrees to use its commercially reasonable efforts to take, or
cause to be taken, all appropriate action, and to do or cause to be done, all things necessary,
proper or advisable to consummate and make effective the transactions as contemplated by this
Contribution Agreement and to cooperate in connection with the foregoing, including commercially
reasonable efforts:
(a) to obtain any necessary waivers, consents and approvals from other parties to material
notes, licenses, agreements and other instruments and obligations;
(b) to obtain any material consents, approvals, authorizations and Permits required to be
obtained under any Law or Order;
(c) to defend all lawsuits or other Legal Proceedings challenging this Contribution Agreement
or the consummation of the transactions as contemplated hereby; and
(d) to effect promptly all necessary filings and notifications including, but not limited to,
filings under the HSR Act, and prompt submissions of information requested by Governmental
Authorities.
37
8.6
New ARI Charter.
Subject to approval of the New ARI Charter by the ARI
Stockholders, ARI will file the New ARI Charter with the Secretary of State of the State of
Delaware.
8.7
Officers and Directors.
The duly elected officers and directors of ARI who hold
office immediately prior to the Effective Time shall be the officers and directors of ARI and shall
thereafter continue to hold such positions until their successors have been duly elected.
8.8
Access to Information
. From the date hereof to the Effective Time, each of the
parties hereto shall afford the officers, employees and representatives of the others, complete
access at all reasonable times to its respective officers, employees, agents, properties, books and
records, as applicable, and shall furnish the others all financial, operating and other data and
information as the others, through their officers, employees or representatives, may reasonably
request.
8.9
Section 351
. For United States federal income tax purposes and any applicable
state or local income tax purposes, the parties hereto recognize that (i) the contributions
described in
Section 2.1
will be treated to the AOG Stockholders as contributions by the
AOG Stockholders of common stock in AOG to ARI in exchange for shares of ARI Common Stock to which
Section 351(a) of the Code applies, (ii) the contributions described in
Section 2.2
will be
treated to Neo Canyon as contributions by Neo Canyon of assets in Neo Canyon to ARI in exchange for
shares of ARI Common Stock to which Section 351(a) of the Code applies and (iii) the
contribution described in
Sections 2.3
and
2.4
will be treated to Lubar and
Yorktown VII as contributions by them of notes payable to ARI in exchange for shares of ARI Common
Stock to which Section 351(a) of the Code applies. No party shall file any income Tax Return or
otherwise take any position for income Tax purposes that is inconsistent with such treatment unless
required to do so pursuant to a determination within the meaning of Section 1313(a) of the Code
or the corresponding provision of state or local income Tax Law. Additionally, each party agrees
to take no action which, alone or in combination with the actions of others, reasonably could
prevent the transactions from qualifying for nonrecognition of gain or loss under Section 351(a) of
the Code (a
Proscribed Action
), including, without limitation, any prearranged sale, contribution
or other disposition of ARI Common Stock. For purposes of this
Section 8.9
, the parties
shall assume that Neo Canyon will sell to third parties in a registered secondary offering in
connection with the ARI Initial Public Offering up to the maximum number of shares that it could
sell without violating the control requirements in Section 351 of the Code and any such sale by
Neo Canyon of such shares of ARI Common Stock shall not, with respect to Neo Canyon, be considered
a Proscribed Action. A Proscribed Action shall not include a distribution of ARI Common Stock by
the AOG Stockholders and Yorktown VII to their respective partners.
8.10
ARI Registration Statement.
Each of the parties hereto shall cooperate in the
preparation and filing of the ARI Registration Statement and to consummate the ARI Initial Public
Offering. As promptly as is practicable following the execution of this Contribution Agreement,
AOG, the AOG Stockholders and Neo Canyon shall cooperate with ARI to cause such ARI Registration
Statement to be filed with the Commission under and pursuant to the provisions of the Securities
Act for the purpose of registering ARI Common Stock for sale to the public in the ARI Initial
Public Offering.
38
8.11
Blue Sky
. ARI will use commercially reasonable efforts to obtain prior to the
Effective Time all necessary Blue Sky Permits and approvals required to permit the issuance of ARI
Common Stock in accordance with the provisions of this Contribution Agreement.
8.12
Notification Of Certain Matters
. Each party hereto will give prompt notice of
(i) the occurrence or non-occurrence of any event, the occurrence or nonoccurrence of which would
be likely to cause any representation or warranty of such Person contained herein to be untrue or
inaccurate in any material respect at or prior to the Effective Time, (ii) any material failure of
any such Person to comply with or satisfy any covenant, condition or agreement to be complied with
or satisfied by such Person hereunder and (iii) any material adverse change in the business,
operations, operating results or condition (financial or otherwise) of such party. The delivery or
deemed delivery of any notice pursuant to this
Section 8.12
shall not be deemed to (i)
modify the representations or warranties hereunder of the party delivering such notice, (ii) modify
the conditions set forth in
Article IX
, or (iii) limit or otherwise affect the remedies
available hereunder to the party receiving such notice.
8.13
Consents and Preferential Rights
. Neo Canyon shall promptly prepare and send,
and Neo Canyon GP shall cause Neo Canyon to promptly prepare and send, (i) notices to the holders
of any required consents to assignment which are set forth on
Schedule 5.3
requesting such
consents and (ii) notices to the holders of any applicable preferential rights to purchase which
are set forth on the Schedules requesting waivers of such preferential rights to purchase. Neo
Canyon shall use, and Neo Canyon GP shall cause Neo Canyon to use, commercially reasonable efforts
to cause such consents and waivers of preferential rights to purchase (or the exercise thereof) to
be obtained and delivered prior to Closing. ARI shall cooperate with Neo Canyon in seeking to
obtain such consents and waivers of preferential rights.
8.14
Assumption and Indemnification
.
(a) FROM AND AFTER CLOSING, AND EXCEPT AS PROVIDED IN
SECTION 8.14(b)
, ARI SHALL
INDEMNIFY, DEFEND AND HOLD HARMLESS NEO CANYON, NEO CANYON GP AND THEIR RESPECTIVE AFFILIATES,
OFFICERS, DIRECTORS, AGENTS, EMPLOYEES AND REPRESENTATIVES FROM AND AGAINST ALL LOSSES (as defined
below in
Section 8.14(c)
) INCURRED OR SUFFERED BY NEO CANYON:
(i) CAUSED BY OR ARISING OUT OF OR RESULTING FROM THE OWNERSHIP, USE OR OPERATION OF
THE NEO CANYON OIL AND GAS PROPERTIES, ON OR AFTER THE CLOSING DATE (INCLUDING, WITHOUT
LIMITATION, ANY OBLIGATION TO PLUG AND ABANDON ANY INACTIVE WELL THAT IS PART OF THE
PROPERTIES OR TO REMEDIATE ANY ENVIRONMENTAL CONDITION WHETHER SUCH ENVIRONMENTAL CONDITION
AROSE PRIOR TO OR AFTER THE CLOSING DATE),
(ii) CAUSED BY OR ARISING OUT OF OR RESULTING FROM ARIS BREACH OF ANY OF ARIS
COVENANTS OR AGREEMENTS THAT SPECIFICALLY SURVIVES CLOSING AS SET FORTH IN
SECTION
11.2
OF THIS CONTRIBUTION AGREEMENT.
39
Upon and after Closing, ARI shall assume and perform all the rights, duties, obligations and
liabilities of ownership and operation of the Neo Canyon Oil and Gas Properties including, without
limitation: (i) all of Neo Canyons express and implied obligations and covenants after the
Closing Date under the terms of the Leases, the Material Contracts, and all other orders, rules and
regulations to which the Neo Canyon Oil and Gas Properties are subject; (ii) responsibility for all
royalties, overriding royalties, rentals, shut-in payments and other burdens or encumbrances to
which the Neo Canyon Oil and Gas Properties are subject accruing after the Closing Date; (iii)
responsibility for compliance with all applicable Laws pertaining to the Neo Canyon Oil and Gas
Properties, and the procurement and maintenance of all permits required by public authorities in
connection with the Neo Canyon Oil and Gas Properties after the Closing Date; and (iv) all other
obligations assumed by ARI under this Contribution Agreement. With respect to non operating
interests in the Neo Canyon Oil and Gas Properties being contributed to ARI under this Contribution
Agreement, ARI shall assume full responsibility and liability for that portion of the foregoing
rights, duties, obligations and liabilities for which non-operators are responsible. Neo Canyon
remains responsible for all costs, expenses and liabilities incurred by Neo Canyon in connection
with the ownership or operation of the Neo Canyon Oil and Gas Properties before the Closing Date,
except (i) those for which ARI indemnifies Neo Canyon, or (ii) those which ARI expressly assumes in
this Contribution Agreement.
(b) FROM AND AFTER CLOSING, AND EXCEPT AS PROVIDED IN
SECTION 8.14(a)
, NEO CANYON AND
NEO CANYON GP SHALL INDEMNIFY, DEFEND AND HOLD HARMLESS ARI AND ITS OFFICERS, DIRECTORS, AGENTS,
EMPLOYEES AND REPRESENTATIVES AGAINST AND FROM NEO CANYONS SHARE OF ALL LOSSES INCURRED OR
SUFFERED BY ARI:
(i) CAUSED BY OR ARISING OUT OF OR RESULTING FROM THE OWNERSHIP, USE OR OPERATION OF
THE NEO CANYON OIL AND GAS PROPERTIES BEFORE THE CLOSING DATE;
(ii) ATTRIBUTABLE TO OR ARISING OUT OF THE ACTIONS, SUITS, OR PROCEEDINGS, IF ANY, SET
FORTH ON
SCHEDULE 5.6
;
(iii) CAUSED BY OR ARISING OUT OF OR RESULTING FROM NEO CANYONS BREACH OF ANY OF ITS
COVENANTS OR AGREEMENTS THAT SPECIFICALLY SURVIVES CLOSING AS SET FORTH IN
SECTION
11.2
OF THIS CONTRIBUTION AGREEMENT.
(c) Losses, for purposes of this
Article VIII
shall mean the amount of any actual
liability, loss, cost, expense, claim, award or judgment incurred or suffered by any Indemnified
Party (as defined in
Section 8.15
) arising out of or resulting from the indemnified matter,
including reasonable fees and expenses of attorneys, consultants, accountants or other agents and
experts reasonably incident to matters indemnified against, and the costs of investigation and/or
monitoring of such matters, and the costs of enforcement of the indemnity; provided, however, that
ARI, Neo Canyon and Neo Canyon GP shall not be entitled to indemnification under this
Section
8.14
for, and Losses shall not include, (i) loss of profits or other consequential damages
suffered by the party claiming indemnification, or (ii) any special
40
or punitive damages (other than
indirect, consequential, special or punitive damages suffered by third Persons and payable by an
Indemnified Person).
(d) The indemnity of each party provided in this
Article VIII
shall be for the benefit
of and extend to such partys present and former Affiliates, and its and their respective
directors, officers, employees, and agents. Any claim for indemnity under this
Article
VIII
by any such Affiliate, director, officer, employee, or agent must be brought and
administered by the applicable party to this Contribution Agreement. No Indemnified Party other
than Neo Canyon, Neo Canyon GP and ARI shall have any rights against Neo Canyon or Neo Canyon GP,
on the one hand, and ARI, on the other hand, under the terms of this
Article VIII
except as
may be exercised on its behalf by ARI or Neo Canyon GP, as applicable, pursuant to this
Section
8.14(d)
. Neo Canyon and ARI may elect to exercise or not exercise indemnification rights under
this
Section 8.14
on behalf of the other Indemnified Parties affiliated with it in its sole
discretion and shall have no liability to any such other Indemnified Party for any action or
inaction under this
Section 8.14
. For purposes of this
Article VIII
, but not for
any other purpose, each of the AOG Stockholders, Lubar and Yorktown VII shall be considered
Affiliates of ARI.
8.15
Indemnification Procedures
.
(a) If any third party asserts any claim against a party to this Contribution Agreement which,
if successful, would entitle the party to indemnification under this
Article VIII
(the
Indemnified Party
), it shall give notice of such claim to the party from whom it intends to seek
indemnification (the
Indemnifying Party
) and the Indemnifying Party shall have the right to
assume the defense and, subject to
Section 8.15(b)
, settlement of such claim at its expense
by representatives of its own choosing acceptable to the Indemnified Party (which acceptance shall
not be unreasonably withheld). The failure of the Indemnified Party to notify the Indemnifying
Party of such claim shall not relieve the Indemnifying Party of any liability that the Indemnifying
Party may have with respect to such claim, except to the extent that the defense is materially
prejudiced by such failure. The Indemnified Party shall have the right to participate in the
defense of such claim at its expense (which expense shall not be deemed to be a Loss), in which
case the Indemnifying Party shall cooperate in providing information to and consulting with the
Indemnified Party about the claim. If the Indemnifying Party fails or does not assume the defense
of any such claim within fifteen (15) days after written notice of such claim has been given by the
Indemnified Party to the Indemnifying Party, the Indemnified Party may defend against or, subject
to
Section 8.15(b)
, settle such claim with counsel of its own choosing at the expense (to
the extent reasonable under the circumstances) of the Indemnifying Party.
(b) If the Indemnifying Party does not assume the defense of a claim involving the asserted
liability of the Indemnified Party under this
Article VIII
, no settlement of such claim
shall be made by the Indemnified Party without the prior written consent of the Indemnifying Party,
which consent shall not be unreasonably withheld or delayed. If the Indemnifying Party assumes the
defense of such a claim, (i) no settlement thereof may be effected by the Indemnifying Party
without the Indemnified Partys consent unless (A) there is no finding or admission of any
violation of Law or any violation of the rights of any Person and no effect on any other claim that
may be made against the Indemnified Party, (B) the sole relief provided is monetary damages that
have been paid in full by the Indemnifying Party, and (C) the settlement includes, as an
unconditional term thereof, the giving by the claimant or the plaintiff
41
to the Indemnified Party of
a release in form and substance reasonably satisfactory to the Indemnified Party, from all
liability in respect of such claim, and (ii) the Indemnified Party shall have no liability with
respect to any compromise or settlement thereof effected without its consent.
8.16
Limits on Indemnification
. Notwithstanding anything to the contrary contained in
this Contribution Agreement:
(a) Neo Canyon and Neo Canyon GP shall not have any obligation to provide indemnification for
Losses with respect to any specific occurrence, event or circumstance giving rise to a right to be
indemnified pursuant to
Section 8.14
unless the amount of the claim giving rise to the
right to be indemnified with respect to such specific occurrence, event or circumstance exceeds
$250,000 (the
Basket Amount
).
(b) ARI shall not have any obligation to provide indemnification for Losses with respect to
any specific occurrence, event or circumstance giving rise to a right to be indemnified pursuant to
Section 8.14
unless the amount of the claim giving rise to the right to be indemnified with
respect to such specific occurrence, event or circumstance exceeds the Basket Amount.
8.17
Further Assurances
. The parties hereto agree to execute and deliver, or cause to
be executed and delivered, such further instruments or documents or take such other action as may
be reasonably necessary or convenient to carry out the transactions contemplated hereby.
8.18
Over-allotment Option.
If the underwriters exercise the over-allotment
option to purchase additional shares of ARI Common Stock in the ARI Initial Public Offering (the
Over-allotment Option
), Neo Canyon shall be entitled to sell in a registered secondary offering
in connection with the Over-allotment Option the maximum number shares of ARI Common Stock owned by
Neo Canyon which would allow the transactions described in
Section 8.9
to qualify under
Section 351 of the Code (as determined by Neo Canyon in its reasonable discretion). ARI shall
apply a portion of the net proceeds received by it from the Over-allotment Option to purchase from
Neo Canyon (at a price per share equal to the initial public offering price per share of ARI Common
Stock less the underwriting discount) that number of its shares of ARI Common Stock equal to the
quotient of (i) a proportionate dollar amount of the gross proceeds received from the
Over-allotment Option based on the ratio that the aggregate purchase price paid to Neo Canyon by
ARI pursuant to
Section 9.2(e)
bears to the aggregate gross proceeds realized by ARI and
Neo Canyon in the ARI Initial Public Offering (excluding any proceeds realized in the
Over-allotment Option),
divided by
(ii) the initial public offering price per share of ARI
Common Stock.
ARTICLE IX.
CONDITIONS
9.1
Conditions to Obligations of Each Party.
Notwithstanding any other provision of
this Contribution Agreement, the respective obligations of each party to effect the transactions
42
contemplated by this Contribution Agreement shall be subject to the fulfillment at or prior to the
Closing Date of the following conditions:
(a) the waiting period (and any extension thereof) applicable to the consummation of the
transactions contemplated herein under the HSR Act shall have expired or been terminated;
(b) no Order shall have been entered and remained in effect in any action or proceeding before
any federal, foreign, state or provincial court or Governmental Authority or other federal,
foreign, state or provincial regulatory or administrative agency or commission that would prevent
or make illegal the consummation of the transactions contemplated herein;
(c) the ARI Registration Statement shall be effective on the Closing Date and all
post-effective amendments filed shall have been declared effective or shall have been withdrawn,
and no stop order suspending the effectiveness thereof shall have been issued and no proceedings
for that purpose shall have been initiated or, to the knowledge of the parties, threatened by the
Commission;
(d) ARI and the underwriters named in the ARI Registration Statement shall have executed an
underwriting agreement (the
Underwriting Agreement
) for a firm commitment underwriting as
described in the ARI Registration Statement; and
(e) all other approvals of Governmental Authorities and of non-governmental persons or
entities shall have been obtained (i) the granting of which is necessary for the consummation of
the transactions contemplated herein and (ii) the non-receipt of which will have an ARI Material
Adverse Effect.
9.2
Conditions to Obligations of Neo Canyon
. Notwithstanding any other provision of
this Contribution Agreement, the obligations of Neo Canyon to effect the transactions contemplated
by this Contribution Agreement shall be subject to the fulfillment at or prior to the Closing Date
of the following conditions:
(a) the conditions set forth in Section 9.1;
(b) the representations and warranties of AOG, each of the AOG Stockholders, Lubar and
Yorktown VII contained in this Contribution Agreement shall have been true and correct as of the
Closing Date (or, if given as of a specific date, at and as of such date), except for such failures
to be true which (i) have been cured prior to the Closing Date or (ii) do not, in the aggregate,
constitute an ARI Material Adverse Effect;
(c) the contributions of the AOG Stockholders, Lubar and Yorktown VII pursuant to
Article
II
and covenants of each of the parties hereto (other than Neo Canyon) to be complied with or
performed on or before the Closing Date pursuant to the terms hereof shall have been duly complied
with or performed, except for such failures to comply or perform which do not, in the aggregate,
constitute an ARI Material Adverse Effect;
(d) (d) the ARI Registration Statement shall have included for sale in a registered secondary
offering by Neo Canyon in connection with the ARI Initial Public Offering
43
the maximum number shares
of ARI Common Stock owned by Neo Canyon which would allow the transactions described in
Section
8.9
to qualify under Section 351 of the Code (as determined by Neo Canyon in its reasonable
discretion) (the
351 Limit Shares
), provided, however, if the managing underwriter or
underwriters advise ARI in writing that, in its view, the total amount of Included Shares proposed
to be sold in such registered secondary offering may adversely affect the success of the ARI
Initial Public Offering or prevent ARI from offering a sufficient number of shares in the ARI
Initial Public Offering to repay its then outstanding indebtedness under its Credit Facility, then
the amount of Included Shares to be offered by Neo Canyon shall be reduced to the extent necessary
to reduce the total amount of securities to be included in the ARI Initial Public Offering to the
amount recommended by such managing underwriter or underwriters;
(e) (e) a portion of the net proceeds from the ARI Initial Public Offering (excluding any
proceeds from the Over-allotment Option) shall be applied to purchase from Neo Canyon (at a price
per share equal to the initial public offering price per share of ARI Common Stock less the
underwriting discount) that number of additional shares of ARI Common Stock equal to the quotient
of (A) the difference of (i) $60,000,000
minus
(ii) the underwriting discount attributable
to $60,000,000 in gross proceeds from the ARI Initial Public Offering
minus
(iii) the
aggregate gross proceeds realized by Neo Canyon from its sale of the 351 Limit Shares,
divided
by
, (B) the initial public offering price per share of ARI Common Stock;
(f) assignment agreements and stock powers in form and substance reasonably acceptable to ARI
evidencing the transfers of the AOG Common Stock, the Lubar Note and the Yorktown Note contemplated
by
Article II
shall have been executed and delivered by each of the AOG Stockholders, Lubar
and Yorktown VII, as applicable;
(g) the Registration Rights Agreement duly executed by all parties thereto, other than Neo
Canyon;
(h) the New ARI Charter shall have been approved by the ARI Stockholders and filed with the
Secretary of State of the State of Delaware; and
(i) the New ARI Bylaws shall have been approved by the ARI Board.
9.3
Conditions to Obligations of ARI.
Notwithstanding any other provision of this
Contribution Agreement, the obligations of ARI to effect the transactions contemplated by this
Contribution Agreement shall be subject to the fulfillment at or prior to the Closing Date of the
following conditions:
(a) the conditions set forth in Section 9.1;
(b) the representations and warranties of AOG, Neo Canyon, each of the AOG Stockholders, Lubar
and Yorktown VII contained in this Contribution Agreement shall have been true and correct as of
the Closing Date (or, if given as of a specific date, at and as of such date), except for such
failures to be true which (i) have been cured prior to the Closing Date or (ii) do not, in the
aggregate, constitute an ARI Material Adverse Effect;
44
(c) the contributions of the AOG Stockholders, Neo Canyon, Lubar and Yorktown VII pursuant to
Article II
and covenants of each of the parties hereto (other than ARI) to be complied with
or performed on or before the Closing Date pursuant to the terms hereof shall have been duly
complied with or performed, except for such failures to comply or perform which do not, in the
aggregate, constitute an ARI Material Adverse Effect;
(d) assignment agreements and stock powers in form and substance reasonably acceptable to ARI
evidencing the transfers of the AOG Common Stock, the Neo Canyon Oil and Gas Properties, the Lubar
Note and the Yorktown Note contemplated by
Article II
shall have been executed and
delivered by each of the AOG Stockholders, Neo Canyon, Lubar and Yorktown VII, as applicable;
(e) the Registration Rights Agreement duly executed by all parties thereto, other than ARI;
(f) the New ARI Charter shall have been approved by the ARI Stockholders and filed with the
Secretary of State of the State of Delaware;
(g) the New ARI Bylaws shall have been approved by the ARI Board; .
(h) the Conveyance in sufficient duplicate originals to allow recording in all appropriate
jurisdictions and offices, duly executed and delivered by Neo Canyon; and
(i) Letters-in-lieu of transfer orders covering the Neo Canyon Oil and Gas Properties, duly
executed and delivered by Neo Canyon.
9.4
Conditions to Obligations of AOG.
Notwithstanding any other provision of this
Contribution Agreement, the obligations of AOG to effect the transactions contemplated by this
Contribution Agreement shall be subject to the fulfillment at or prior to the Closing Date of the
following conditions:
(a) the conditions set forth in
Section 9.1
;
(b) the representations and warranties of Neo Canyon and ARI contained in this Contribution
Agreement shall have been true and correct as of the Closing Date (or, if given as of a specific
date, at and as of such date), except for such failures to be true which (i) have been cured prior
to the Closing Date or (ii) do not, in the aggregate, constitute an ARI Material Adverse Effect;
(c) the contributions of the Neo Canyon pursuant to
Article II
and covenants of each
of the parties hereto (other than ARI) to be complied with or performed on or before the Closing
Date pursuant to the terms hereof shall have been duly complied with or performed, except for such
failures to comply or perform which do not, in the aggregate, constitute an ARI Material Adverse
Effect;
(d) assignment agreements in form and substance reasonably acceptable to ARI evidencing the
transfers of the Neo Canyon Oil and Gas Properties contemplated by
Article II
shall have
been executed and delivered by New Canyon;
45
(e) the Conveyance in sufficient duplicate originals to allow recording in all appropriate
jurisdictions and offices, duly executed and delivered by Neo Canyon; and
(f) Letters-in-lieu of transfer orders covering the Neo Canyon Oil and Gas Properties, duly
executed and delivered by Neo Canyon.
9.5
Conditions to Obligations of each of the AOG Stockholders, Lubar and Yorktown VII.
Notwithstanding any other provision of this Contribution Agreement, the obligations of each of the
AOG Stockholders, Lubar and Yorktown VII to effect the transactions contemplated by this
Contribution Agreement shall be subject to the fulfillment at or prior to the Closing Date of the
following conditions:
(a) the conditions set forth in
Section 9.1
;
(b) the representations and warranties of Neo Canyon and ARI contained in this Contribution
Agreement shall have been true and correct as of the Closing Date (or, if given as of a specific
date, at and as of such date), except for such failures to be true which (i) have been cured prior
to the Closing Date or (ii) do not, in the aggregate, constitute an ARI Material Adverse Effect;
(c) the contributions of Neo Canyon pursuant to
Article II
and covenants of each of
the parties hereto (other than the AOG Stockholders, Lubar and Yorktown VII) to be complied
with or performed on or before the Closing Date pursuant to the terms hereof shall have been
duly complied with or performed, except for such failures to comply or perform which do not, in the
aggregate, constitute an ARI Material Adverse Effect;
(d) assignment agreements and stock powers in form and substance reasonably acceptable to ARI
evidencing the transfers of the Neo Canyon Oil and Gas Properties contemplated by
Article
II
shall have been executed and delivered by Neo Canyon;
(e) the Registration Rights Agreement duly executed by all parties thereto, other than the AOG
Stockholders, Lubar and Yorktown VII;
(f) the New ARI Charter shall have been approved by the ARI Stockholders and filed with the
Secretary of State of the State of Delaware;
(g) the New ARI Bylaws shall have been approved by the ARI Board; .
(h) the Conveyance in sufficient duplicate originals to allow recording in all appropriate
jurisdictions and offices, duly executed and delivered by Neo Canyon; and
(i) Letters-in-lieu of transfer orders covering the Neo Canyon Oil and Gas Properties, duly
executed and delivered by Neo Canyon.
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ARTICLE X.
TERMINATION
10.1
Termination
. This Contribution Agreement may be terminated and the transactions
contemplated herein may be abandoned at any time prior to the Effective Time:
(a) by any party hereto if the Effective Time shall not have occurred on or before March 31,
2008 (unless the Effective Time has not occurred as the result of a breach of the terms hereof by
the party desiring to exercise the termination right, which date may be extended by mutual
agreement of the parties hereto);
(b) by any party hereto if a final unappealable Order to restrain, enjoin or otherwise
prevent, or awarding substantial damages in connection with, consummation of this Contribution
Agreement or the transactions contemplated in connection herewith shall have been entered;
(c) with the written consent of (i) ARI, (ii) each of the AOG Stockholders, (iii) Neo Canyon,
(iv) Lubar and (v) Yorktown VII;
(d) by Neo Canyon, if ARI or AOG consummates a financing transaction or an acquisition that
reduces Neo Canyons pro forma ownership percentage in ARI (after giving effect to
Sections
2.1
and
2.2
, but excluding any reduction resulting from the ARI Initial Public Offering
and the issuance of shares pursuant to
Sections
2.3
and
2.4
) by 17.5% or
more;
(e) by ARI, if ARI receives an Acquisition Proposal that the ARI Board determines in good
faith is reasonably likely to be consummated and is in the best interests of ARI and its
stockholders and necessary in order for the ARI Board to discharge its fiduciary duties to
ARIs stockholders under applicable Law; provided, however, that, prior to any such termination,
ARI shall use its reasonable best efforts to cause the Neo Canyon Oil and Gas Properties to be
included in such Acquisition Proposal; or
(f) by AOG, if AOG receives an Acquisition Proposal that the AOG Board determines in good
faith is reasonably likely to be consummated and is in the best interests of AOG and its
stockholders and necessary in order for the AOG Board to discharge its fiduciary duties to AOGs
stockholders under applicable Law.
10.2
Effect of Termination
. In the event of any termination of this Contribution
Agreement pursuant to
Section 10.1
, the parties hereto shall have no obligation or
liability to any other party hereto except the provisions of this
Section 10.2
and
Sections 10.3
,
11.5
,
11.6
,
11.8
,
11.9
,
11.10
, and
11.12
hereof shall survive any such termination and, except as provided in this
Section
10.2
, all documents executed in connection with this Contribution Agreement shall be null and
void.
10.3
Fees and Expenses
. Each party shall bear their own costs and expenses incurred
by it hereto in connection with this Contribution Agreement and the transactions contemplated
hereby.
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ARTICLE XI.
MISCELLANEOUS
11.1
Waiver And Amendment
. Any provision of this Contribution Agreement may be waived
at any time by the party that is entitled to the benefits thereof. This Contribution Agreement may
not be amended or supplemented at any time, except by an instrument in writing signed on behalf of
each party hereto.
11.2
Nonsurvival of Representations and Warranties
. No representation and warranty
made in this Contribution Agreement shall survive the Effective Time. This
Section 11.2
shall not limit the term of any covenant or agreement which by its terms contemplates performance
after the Closing Date.
11.3
Assignment.
This Contribution Agreement and all of the provisions hereof shall
be binding upon and inure to the benefit of the parties hereto and their respective successors,
heirs, devisees and assigns. Except as set forth in this Contribution Agreement, this Contribution
Agreement shall not be assignable until after the Closing Date (except by inheritance or devise) by
the parties hereto, except with the prior written consent of the other parties.
11.4
Notices.
All notices, requests, claims, demands and other communications
hereunder shall be in writing and shall be deemed to have been duly given when delivered if
delivered in person, by cable, telegram, telex, or telecopy and shall be deemed to have been duly
given three (3) Business Days after deposit with a United States post office if delivered by
registered or certified mail (postage prepaid, return receipt requested) to the respective parties
as follows:
If to ARI, AOG, the AOG Stockholders or Yorktown VII:
Approach Resources Inc.
6300 Ridglea Place, Suite 1107
Fort Worth, Texas 76116
Fax: (817) 989-9001
Attn: J. Ross Craft
with a copy to:
Thompson & Knight LLP
1700 Pacific Avenue, Suite 3300
Dallas, TX 75201
Fax: (214) 969-1751
Attn: Jeffrey A. Zlotky, Esq.
48
if to Neo Canyon or Neo Canyon GP:
Neo Canyon Exploration, L.P.
325 North Saint Paul, Suite 4300
Dallas, Texas 75201
Fax: (214) 969-7433
Attn: James Cleo Thompson, Jr.
with a copy to:
Carrington, Coleman, Sloman & Blumenthal, L.L.P.
901 Main Street, Suite 5500
Dallas Texas, 75202
Fax: (214) 758-3732
Attn: David G. Drumm, Esq.
If to Lubar:
Lubar Equity Fund, LLC
700 N. Water Street, Suite 1200
Milwaukee, WI 53202
Fax: (414) 291-9061
Attn: David Kuehl
or to such other address as any party may have furnished to the others in writing in
accordance herewith, except that notices of change of address shall only be effective upon receipt.
11.5
Governing Law
. This Contribution Agreement shall be governed by and construed in
accordance with the substantive law of the State of Delaware without giving effect to the
principles of conflicts of law thereof.
11.6
Severability
. If any term or other provisions of this Contribution Agreement is
invalid, illegal or incapable of being enforced by any rule of Law or public policy, all other
conditions and provisions of this Contribution Agreement shall nevertheless remain in full force
and effect so long as the economic or legal substance of the transactions contemplated hereby is
not affected in any manner material to any party. Upon such determination that any term or other
provision is invalid, illegal or incapable of being enforced, the parties hereto shall negotiate in
good faith to modify this Contribution Agreement so as to effect the original intent of the parties
as closely as possible.
11.7
Counterparts
. This Contribution Agreement may be executed in counterparts, each
of which shall be an original document, but all of which together shall constitute one and the same
agreement.
11.8
Headings.
The section headings herein are for convenience only and are not
intended to be part of or to affect the meaning or interpretation of the Contribution Agreement.
49
11.9
Enforcement Of The Contribution Agreement
. The parties hereto agree that
irreparable damage would occur in the event that any of the provisions of this Contribution
Agreement were not performed in accordance with their specific terms or otherwise breached. It is
accordingly agreed that the parties hereto shall be entitled to any injunction or injunctions to
prevent breaches of this Contribution Agreement and to enforce specifically the terms and
provisions hereof, this being in addition to any other remedies to which they are entitled at law
or in equity. In addition, each of the parties hereto consents to submit itself to the personal
jurisdiction of any federal or state court sitting in the State of Delaware in the event any
dispute arises out of this Contribution Agreement and agrees that it will not attempt to deny or
defeat such personal jurisdiction by motion or other request for leave from any such court.
11.10
Entire Agreement; Third Party Beneficiaries
. This Contribution Agreement,
including the documents and information supplied in writing, and instruments referred to herein,
constitute the entire agreement and supersedes all other prior agreements, and understandings, both
oral and written, among the parties or any of them, with respect to the subject matter hereof. This
Contribution Agreement shall be binding upon and inure solely to the benefit of the parties hereto,
and nothing in this Contribution Agreement, including the documents and information supplied in
writing, and instruments referred to herein, express or implied, is intended to confer upon any
other person any rights or remedies of any nature whatsoever under or by reason of this
Contribution Agreement.
11.11
Certain Assignments
. Each of the parties hereto acknowledge and agree that each
AOG Stockholder, Lubar and Yorktown VII may transfer and assign their respective shares, or their
right to receive such shares, of ARI Common Stock to be received pursuant to
Section 2.5
to
an Affiliate of such AOG Stockholder, Lubar and Yorktown VII, respectively; provided, however, that
each transferee pursuant to this
Section 11.11
shall in connection with such transfer agree
to be bound by, and shall become a party to, this Contribution Agreement.
11.12
Representation
. The parties hereto agree that in connection with the
negotiation and execution of this Contribution Agreement, Thompson & Knight LLP has represented
ARI, AOG, the AOG Stockholders and Yorktown VII. Each of Neo Canyon, Neo Canyon GP and Lubar
hereby acknowledges that it has been advised to consult with its own counsel regarding legal
matters concerning this Contribution Agreement and has been afforded the opportunity to consult
with counsel that such party deems advisable in connection with the negotiation and execution of
this Contribution Agreement.
11.13
Joinder
. Neo Canyon GP is joining in this Contribution Agreement for the
purpose of making specified representations and warranties covenants and conditions as set forth
herein, including those set forth in
Articles V, VIII, IX and XI
.
[Remainder of page intentionally left blank]
[Signature pages follow]
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IN WITNESS WHEREOF, the parties to this Contribution Agreement have caused it to be duly
executed as of the date first above written.
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ARI:
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APPROACH RESOURCES INC.
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By:
Name:
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/s/ J. Ross Craft
J. Ross Craft
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Title:
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President and Chief Executive Officer
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AOG:
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APPROACH OIL & GAS INC.
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By:
Name:
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/s/ J. Ross Craft
J. Ross Craft
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Title:
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President and Chief Executive Officer
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NEO CANYON:
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NEO CANYON EXPLORATION, L.P.
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By: J. Cleo Thompson Petroleum Management,
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L.L.C., its general partner
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By:
Name:
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/s/ James Cleo Thompson, Jr.
James Cleo Thompson, Jr.
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Title:
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Member-Manager
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NEO CANYON GP:
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J. CLEO THOMPSON PETROLEUM MANAGEMENT, L.L.C.
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By:
Name:
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/s/ James Cleo Thompson, Jr.
James Cleo Thompson, Jr.
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Title:
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Member-Manager
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AOG STOCKHOLDERS:
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YORKTOWN ENERGY PARTNERS V, L.P.
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By: Yorktown V Company LLC, its general partner
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By:
Name:
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/s/ W. Howard Keenan, Jr.
W. Howard Keenan, Jr.
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Title:
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Managing Member
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YORKTOWN ENERGY PARTNERS VI, L.P.
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By: Yorktown VI Company LP, its general partner
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By: Yorktown VI Associates LLC, its general partner
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By:
Name:
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/s/ W. Howard Keenan, Jr.
W. Howard Keenan, Jr.
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Title:
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Managing Member
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LUBAR:
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LUBAR EQUITY FUND, LLC
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By: Lubar & Co., Incorporated, Manager
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By:
Name:
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/s/ David Lubar
David Lubar
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Title:
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President
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YORKTOWN VII:
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YORKTOWN ENERGY PARTNERS VII, L.P.
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By: Yorktown VII Company LP, its general partner
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By: Yorktown VII Associates LLC, its general partner
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By:
Name:
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/s/ W. Howard Keenan, Jr.
W. Howard Keenan, Jr.
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Title:
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Managing Member
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Exhibit A
AOG OIL AND GAS PROPERTIES LEASES AND WELLS
Exhibit A-1
Exhibit B
ARI OIL AND GAS PROPERTIES LEASES AND WELLS
Exhibit B-1
Exhibit C
NEO CANYON OIL AND GAS PROPERTIES LEASES AND WELLS
Exhibit C-1
Exhibit D
FORM OF CONVEYANCE
Exhibit D-1
Exhibit E
REGISTRATION RIGHTS AGREEMENT
Exhibit E-1
Exhibit 10.9
AMENDED AND RESTATED
CREDIT AGREEMENT
AMONG
APPROACH RESOURCES I, LP
AS BORROWER,
THE FROST NATIONAL BANK
AND THE INSTITUTIONS NAMED HEREIN
AS LENDERS,
AND
THE FROST NATIONAL BANK
AS ADMINISTRATIVE AGENT
FEBRUARY 15, 2007
$100,000,000 REVOLVING CREDIT
TABLE OF CONTENTS
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Page No.
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1.
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Definitions
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1
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2.
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Commitments of Lenders
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10
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(a)
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Terms of Commitment
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10
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(b)
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Procedure for Borrowing
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10
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(c)
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Letters of Credit
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11
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(d)
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Procedure for Obtaining Letters of Credit
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12
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(e)
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Outstanding Letters of Credit
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12
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(f)
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Voluntary Reduction of Borrowing Base
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12
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(g)
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Mandatory Borrowing Base Reductions
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12
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(h)
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Several Obligations
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13
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(i)
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Type and Number of Advances
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13
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3.
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Notes Evidencing Loans
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13
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(a)
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Form of Notes
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13
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(b)
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Issuance of Additional Notes
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13
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(c)
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Interest Rates
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13
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(d)
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Payment of Interest
|
|
|
13
|
|
|
|
(e)
|
|
Payment of Principal
|
|
|
14
|
|
|
|
(f)
|
|
Payment to Lenders
|
|
|
14
|
|
|
|
(g)
|
|
Sharing of Payments, Etc.
|
|
|
14
|
|
|
|
(h)
|
|
Non-Receipt of Funds by Agent
|
|
|
14
|
|
4.
|
|
Interest Rates
|
|
|
15
|
|
|
|
(a)
|
|
Options
|
|
|
15
|
|
|
|
(b)
|
|
Interest Rate Determination
|
|
|
16
|
|
|
|
(c)
|
|
Conversion Option
|
|
|
16
|
|
|
|
(d)
|
|
Recoupment
|
|
|
16
|
|
|
|
(e)
|
|
Interest Rates Applicable After Default
|
|
|
16
|
|
5.
|
|
Special Provisions Relating to Loans
|
|
|
16
|
|
|
|
(a)
|
|
Unavailability of Funds or Inadequacy of Pricing
|
|
|
17
|
|
|
|
(b)
|
|
Change in Laws
|
|
|
17
|
|
|
|
(c)
|
|
Increased Cost or Reduced Return
|
|
|
17
|
|
|
|
(d)
|
|
Discretion of Lender as to Manner of Funding
|
|
|
19
|
|
|
|
(e)
|
|
Breakage Fees
|
|
|
19
|
|
6.
|
|
Collateral Security
|
|
|
20
|
|
7.
|
|
Borrowing Base
|
|
|
21
|
|
|
|
(a)
|
|
Initial Borrowing Base
|
|
|
21
|
|
|
|
(b)
|
|
Subsequent Determinations of Borrowing Base
|
|
|
21
|
|
8.
|
|
Fees
|
|
|
22
|
|
|
|
(a)
|
|
Up-Front Fee
|
|
|
22
|
|
|
|
(b)
|
|
Unused Commitment Fee
|
|
|
22
|
|
9.
|
|
Prepayments
|
|
|
23
|
|
|
|
(a)
|
|
Voluntary Prepayments
|
|
|
23
|
|
|
|
(b)
|
|
Mandatory Prepayment For Borrowing Base Deficiency
|
|
|
23
|
|
i
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Page No.
|
|
10.
|
|
Representations and Warranties
|
|
|
23
|
|
|
|
(a)
|
|
Organization and Qualification
|
|
|
23
|
|
|
|
(b)
|
|
Power and Authority
|
|
|
23
|
|
|
|
(c)
|
|
Binding Obligations
|
|
|
24
|
|
|
|
(d)
|
|
No Legal Bar or Resultant Lien
|
|
|
24
|
|
|
|
(e)
|
|
No Consent
|
|
|
24
|
|
|
|
(f)
|
|
Financial Condition
|
|
|
24
|
|
|
|
(g)
|
|
Liabilities
|
|
|
24
|
|
|
|
(h)
|
|
Litigation
|
|
|
25
|
|
|
|
(i)
|
|
Taxes; Governmental Charges
|
|
|
25
|
|
|
|
(j)
|
|
Titles, Etc.
|
|
|
25
|
|
|
|
(k)
|
|
Defaults
|
|
|
26
|
|
|
|
(l)
|
|
Casualties; Taking of Properties
|
|
|
26
|
|
|
|
(m)
|
|
Use of Proceeds; Margin Stock
|
|
|
26
|
|
|
|
(n)
|
|
Location of Business and Offices
|
|
|
26
|
|
|
|
(o)
|
|
Compliance with the Law
|
|
|
26
|
|
|
|
(p)
|
|
No Material Misstatements
|
|
|
27
|
|
|
|
(q)
|
|
Not A Utility
|
|
|
27
|
|
|
|
(r)
|
|
ERISA
|
|
|
27
|
|
|
|
(s)
|
|
Intentionally Deleted
|
|
|
27
|
|
|
|
(t)
|
|
No Subsidiaries
|
|
|
27
|
|
|
|
(u)
|
|
Environmental Matters
|
|
|
27
|
|
|
|
(v)
|
|
Liens
|
|
|
27
|
|
|
|
(w)
|
|
Solvency
|
|
|
28
|
|
|
|
(x)
|
|
Insurance
|
|
|
28
|
|
11.
|
|
Conditions of Lending
|
|
|
28
|
|
12.
|
|
Affirmative Covenants
|
|
|
30
|
|
|
|
(a)
|
|
Financial Statements and Reports of Borrower, Guarantor
|
|
|
30
|
|
|
|
(b)
|
|
Hedging Report
|
|
|
31
|
|
|
|
(c)
|
|
Additional Information
|
|
|
31
|
|
|
|
(d)
|
|
Certificates of Compliance
|
|
|
31
|
|
|
|
(e)
|
|
Taxes and Other Liens
|
|
|
31
|
|
|
|
(f)
|
|
Compliance with Laws
|
|
|
31
|
|
|
|
(g)
|
|
Further Assurances
|
|
|
32
|
|
|
|
(h)
|
|
Performance of Obligations
|
|
|
32
|
|
|
|
(i)
|
|
Insurance
|
|
|
32
|
|
|
|
(j)
|
|
Accounts and Records
|
|
|
32
|
|
|
|
(k)
|
|
Right of Inspection
|
|
|
32
|
|
|
|
(l)
|
|
Notice of Certain Events
|
|
|
33
|
|
|
|
(m)
|
|
Environmental Reports and Notices
|
|
|
33
|
|
|
|
(n)
|
|
Compliance and Maintenance
|
|
|
33
|
|
|
|
(o)
|
|
Operation of Properties
|
|
|
34
|
|
|
|
(p)
|
|
Compliance with Leases and Other Instruments
|
|
|
34
|
|
|
|
(q)
|
|
Certain Additional Assurances Regarding Maintenance and Operations of
|
|
|
|
|
|
|
|
|
Properties
|
|
|
34
|
|
|
|
(r)
|
|
Sale of Certain Assets/Prepayment of Proceeds
|
|
|
35
|
|
|
|
(s)
|
|
Title Matters
|
|
|
35
|
|
ii
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Page No.
|
|
|
|
(t)
|
|
Change of Principal Place of Business
|
|
|
35
|
|
|
|
(u)
|
|
Additional Collateral
|
|
|
35
|
|
13.
|
|
Negative Covenants
|
|
|
36
|
|
|
|
(a)
|
|
Negative Pledge
|
|
|
36
|
|
|
|
(b)
|
|
Current Ratio
|
|
|
36
|
|
|
|
(c)
|
|
Consolidations and Mergers
|
|
|
36
|
|
|
|
(d)
|
|
Limitation on Additional Indebtedness
|
|
|
36
|
|
|
|
(e)
|
|
Restricted Payments
|
|
|
37
|
|
|
|
(f)
|
|
Rate Management Transactions
|
|
|
37
|
|
|
|
(g)
|
|
Certain Transactions
|
|
|
38
|
|
|
|
(h)
|
|
Intentionally Deleted
|
|
|
38
|
|
|
|
(i)
|
|
Limitation on Investments and New Businesses
|
|
|
38
|
|
|
|
(j)
|
|
Limitation on Credit Extensions
|
|
|
38
|
|
|
|
(k)
|
|
Fiscal Year
|
|
|
38
|
|
|
|
(l)
|
|
Certain Agreements
|
|
|
38
|
|
|
|
(m)
|
|
Lines of Business
|
|
|
38
|
|
14.
|
|
Events of Default
|
|
|
38
|
|
15.
|
|
Agent and Lenders
|
|
|
41
|
|
|
|
(a)
|
|
Appointment and Authorization
|
|
|
41
|
|
|
|
(b)
|
|
Note Holders
|
|
|
42
|
|
|
|
(c)
|
|
Consultation with Counsel
|
|
|
42
|
|
|
|
(d)
|
|
Documents
|
|
|
42
|
|
|
|
(e)
|
|
Resignation or Removal of Agent
|
|
|
42
|
|
|
|
(f)
|
|
Responsibility of Agent
|
|
|
43
|
|
|
|
(g)
|
|
Independent Investigation
|
|
|
44
|
|
|
|
(h)
|
|
Indemnification
|
|
|
44
|
|
|
|
(i)
|
|
Benefit of Section 15
|
|
|
44
|
|
|
|
(j)
|
|
Pro Rata Treatment
|
|
|
44
|
|
|
|
(k)
|
|
Assumption as to Payments
|
|
|
45
|
|
|
|
(l)
|
|
Other Financings
|
|
|
45
|
|
|
|
(m)
|
|
Interests of Lenders
|
|
|
45
|
|
|
|
(n)
|
|
Investments
|
|
|
45
|
|
|
|
(o)
|
|
Delegation to Affiliates
|
|
|
46
|
|
|
|
(p)
|
|
Execution of Collateral Documents
|
|
|
46
|
|
|
|
(q)
|
|
Collateral Releases
|
|
|
46
|
|
16.
|
|
Exercise of Rights
|
|
|
46
|
|
17.
|
|
Notices
|
|
|
46
|
|
18.
|
|
Expenses
|
|
|
47
|
|
19.
|
|
Indemnity
|
|
|
47
|
|
20.
|
|
Non-Liability of Lenders
|
|
|
48
|
|
21.
|
|
Governing Law
|
|
|
48
|
|
22.
|
|
Invalid Provisions
|
|
|
48
|
|
23.
|
|
Maximum Interest Rate
|
|
|
48
|
|
24.
|
|
Amendments
|
|
|
49
|
|
25.
|
|
Multiple Counterparts
|
|
|
49
|
|
26.
|
|
Conflict
|
|
|
50
|
|
iii
|
|
|
|
|
|
|
|
|
Page No.
|
27.
|
|
Survival
|
|
50
|
28.
|
|
Parties Bound
|
|
50
|
29.
|
|
Assignments and Participations
|
|
50
|
30.
|
|
Choice of Forum: Consent to Service of Process and Jurisdiction
|
|
52
|
31.
|
|
Waiver of Jury Trial
|
|
52
|
32.
|
|
Other Agreements
|
|
52
|
33.
|
|
Financial Terms
|
|
52
|
34.
|
|
Tri-Party Loan
|
|
52
|
35.
|
|
USA Patriot Act Notice
|
|
52
|
36.
|
|
Original Credit Agreement
|
|
52
|
|
|
|
|
|
Exhibits
|
|
|
|
|
Exhibit A
|
|
-
|
|
Form of Notice of Borrowing
|
Exhibit B
|
|
-
|
|
Form of Note
|
Exhibit C
|
|
-
|
|
Form of Certificate of Compliance
|
Exhibit D
|
|
-
|
|
Form of Assignment and Acceptance Agreement
|
|
|
|
|
|
Schedules
|
|
|
|
|
Schedule 1
|
|
-
|
|
Liens
|
Schedule 2
|
|
-
|
|
Financial Condition
|
Schedule 2(e)
|
|
-
|
|
Existing Letters of Credit
|
Schedule 3
|
|
-
|
|
Liabilities
|
Schedule 4
|
|
-
|
|
Litigation
|
Schedule 5
|
|
-
|
|
Subsidiaries
|
Schedule 6
|
|
-
|
|
Environmental Matters
|
iv
AMENDED AND RESTATED CREDIT AGREEMENT
THIS AMENDED AND RESTATED CREDIT AGREEMENT
(the Agreement) executed as of the 15th day of
February, 2007, by and among
APPROACH RESOURCES I, LP,
a Texas limited partnership (Borrower),
and each of the financial institutions which is a party hereto (as evidenced by the signature pages
to this Agreement) or which may from time to time become a party hereto pursuant to the provisions
of Section 29 hereof or any successor or permitted assignee thereof (collectively, Lenders, and
individually, Lender), and
THE FROST NATIONAL BANK,
a national banking association (Frost), as
Administrative Agent (Agent).
W I T N E S S E T H:
In consideration of the mutual covenants and agreements herein contained, the parties hereby
agree as follows:
1.
Definitions
. When used herein the terms Agent, Agreement, Borrower, Frost, Lender and
Lenders, shall have the meanings indicated above. When used herein the following terms shall
have the following meanings:
Accounting Principles
means generally accepted accounting principles in effect from
time to time, applied in a manner consistent with prior periods.
Advance
means a borrowing hereunder (i) made by some or all of Lenders on the same
Borrowing Date, or (ii) converted or continued by Lenders on the same date of conversion or
continuation, consisting, in either case, of the aggregate amount of the several Loans of the same
type and, in the case of Eurodollar Loans, for the same Interest Period.
Affiliate
means any Person which, directly or indirectly, controls, is controlled by
or is under common control with the relevant Person. For the purposes of this definition,
control (including, with correlative meanings, the terms controlled by and under common
control with), as used with respect to any Person, shall mean a member of the board of directors,
a partner or an officer of such Person, or any other Person with possession, directly or
indirectly, of the power to direct or cause the direction of the management and policies of such
Person, through the ownership (of record, as trustee, or by proxy) of voting shares, partnership
interests or voting rights, through a management contract or otherwise. Any Person owning or
controlling directly or indirectly ten percent or more of the voting shares, partnership interests
or voting rights, or other equity interest of another Person shall be deemed to be an Affiliate of
such Person.
Applicable Rate
means, for any day, with respect to any Base Rate Loan or Eurodollar
Loan, or with respect to the Unused Commitment Fees payable hereunder, as the case may be, the
applicable rate per annum set forth below under the caption Base Rate Margin, Eurodollar Margin
or Unused Commitment Fee Rate, as the case may be, based upon the Borrowing Base Usage applicable
on such date:
1
|
|
|
|
|
|
|
|
|
|
|
|
|
Unused
|
Borrowing Base
|
|
Eurodollar
|
|
Base Rate
|
|
Commitment
|
Usage
|
|
Margin
|
|
Margin
|
|
Fee Rate
|
³
90%
|
|
200 b.p.
|
|
0 b.p.
|
|
37.5 b.p.
|
|
|
|
|
|
|
|
³
75% and < 90%
|
|
175 b.p.
|
|
0 b.p.
|
|
37.5 b.p.
|
|
|
|
|
|
|
|
³
50% and < 75%
|
|
150 b.p.
|
|
0 b.p.
|
|
37.5 b.p.
|
|
|
|
|
|
|
|
< 50%
|
|
125 b.p.
|
|
0. b.p.
|
|
37.5 b.p.
|
|
Each change in the Applicable Rate shall apply during the period commencing on the effective
date of such change and ending on the date immediately preceding the effective date of the next
change.
Approach Delaware
means Approach Delaware, LLC, a Delaware limited liability company
and the sole limited partner of Borrower.
Approach Operating
means Approach Operating, LLC, a Delaware limited liability company
and the sole general partner of Borrower.
Approach Resources
means Approach Resources Inc., a Delaware corporation and sole
member of Guarantors.
Assignment and Acceptance
means a document substantially in the form of Exhibit D
hereto.
Available Commitment
means, at any time, the Commitment then in effect minus the Total
Outstandings.
Base Rate
means, as of any date, a rate of interest per annum equal to the Prime Rate
for such date, plus the Applicable Rate.
Base Rate Loan
means any loan during any period which bears interest based upon the
Base Rate or which would bear interest based upon the Base Rate if the Maximum Rate ceiling was not
in effect at that particular time.
Borrowing Base
means, as of any date, the value assigned by Lenders from time to time
to the Borrowing Base Properties pursuant to Section 7 hereof.
Borrowing Base Deficiency
is used herein as defined in Section 9(b) hereof.
Borrowing Base Properties
means the Oil and Gas Properties.
Borrowing Date
means the date elected by Borrower pursuant to Section 2(b) hereof for
2
an Advance on the Loan.
Business Day
means (i) with respect to any borrowing, payment or note selection of
Eurodollar Loans, a day (other than Saturdays or Sundays) on which banks are legally open for
business in Fort Worth, Texas and on which dealings in United States dollars are carried on in the
London interbank market, and (ii) for all other purposes a day (other than Saturdays and Sundays)
on which banks are legally open for business in Fort Worth, Texas.
Capital Lease
means any lease of property, real or personal, which would be
capitalized on a balance sheet of the lessee prepared in accordance with Accounting Principles.
Change of Control
means the acquisition by any Person or group of Persons acting
together, of a direct interest in more than a majority of the voting power of the voting stock of
or membership interests in Borrower, by way of merger or consolidation or otherwise.
Collateral
shall have the meaning assigned in Section 6 hereof.
Collateral Documents
is used collectively to mean this Agreement, all Deeds of Trust,
Mortgages, Security Agreements, Assignments of Production and Financing Statements, the Guaranties
and other documents covering the Oil and Gas Properties and related personal property, equipment,
oil and gas inventory and proceeds of the foregoing and other collateral documents, all such
documents to be in form and substance reasonably satisfactory to Agent.
Commitment
means (A) for all Lenders, the lesser of (i) $100,000,000 or (ii) the
Borrowing Base, as reduced or increased from time to time pursuant to Sections 2 and 7 hereof, and
(B) as to any Lender, its obligation to make Advances hereunder in amounts not exceeding, in the
aggregate, an amount equal to such Lenders Commitment Percentage times the total Commitment as of
any date. The Commitment of each Lender hereunder shall be adjusted from time to time to reflect
assignments made by such Lender pursuant to Section 29 hereof. Each reduction in the Commitment
shall result in a Pro Rata reduction in each Lenders Commitment.
Commitment Percentage
means for each Lender the percentage set forth opposite the
Lenders name on the signature page hereto. The Commitment Percentage of each Lender hereunder
shall be adjusted from time to time to reflect assignments made by such Lender pursuant to Section
29 hereof.
Current Assets
means, as of any date, the current assets which would be reflected on a
balance sheet of Borrower prepared as of such date in accordance with Accounting Principles;
provided that Borrowers Current Assets shall include the Available Commitment, and Current Assets
shall not include the amount of any non-cash items as a result of the application of Financial
Accounting Standards Board Statement No. 133 and any subsequent amendments thereto or the fair
value of any Rate Management Transaction or any non-hedge derivative contract (whether deemed
effective or non-effective).
Current Liabilities
means, as of any date, the current liabilities which would be
reflected on a balance sheet of Borrower prepared as of such date in accordance with Accounting
Principles, but excluding any liabilities as a result of the application of Financial Accounting
Standards Board Statement No. 133 and any subsequent amendments thereto or the fair value of
3
any Rate Management Transaction or any non-hedge derivative contract (whether deemed effective
or non-effective).
Current Ratio
means the ratio of Current Assets to Current Liabilities.
Dollar or $
means United States dollars.
Default
means all the events specified in Section 14 hereof, regardless of whether
there shall have occurred any passage of time or giving of notice, or both, that would be necessary
in order to constitute such event as an Event of Default.
Default Rate
is used herein as defined in Section 4(e) hereof.
Effective Date
means the date of this Agreement.
Eligible Assignee
means any of (i) a Lender or any Affiliate of a Lender; (ii) a
commercial bank organized under the laws of the United States, or any state thereof, and having a
combined capital and surplus of at least $100,000,000; (iii) a commercial bank organized under the
laws of any other country which is a member of the Organization for Economic Cooperation and
Development, or a political subdivision of any such country, and having a combined capital and
surplus of at least $100,000,000.00, provided that such bank is acting through a branch or agency
located in the United States; and (iv) a Person that is primarily engaged in the business of
commercial lending and that (A) is a subsidiary of a Lender, (B) a subsidiary of a Person of which
a Lender is a subsidiary, or (C) a Person of which a Lender is a subsidiary; provided, however,
that no Affiliate of Borrower shall be an Eligible Assignee.
Engineered Value
is used herein as defined in Section 6 hereof.
Environmental Certificate
shall have the meaning assigned to it in Section 4.2 hereof.
Environmental Laws
means the Comprehensive Environmental Response, Compensation and
Liability Act of 1980, as amended by the Superfund Amendments and Reauthorization Act of 1986, 42
U.S.C.A. §9601, et seq., the Resource Conservation and Recovery Act, as amended by the Hazardous
Solid Waste Amendment of 1984, 42 U.S.C.A. §6901, et seq., the Clean Water Act, 33 U.S.C.A. §1251,
et seq., the Clean Air Act, 42 U.S.C.A. §1251, et seq., the Toxic Substances Control Act, 15
U.S.C.A. §2601, et seq., The Oil Pollution Act of 1990, 33 U.S.G. §2701, et seq., and all other
laws, statutes, codes, acts, ordinances, orders, judgments, decrees, injunctions, rules,
regulations, orders, permits and restrictions of any federal, state, county, municipal and other
governments, departments, commissions, boards, agencies, courts, authorities, officials and
officers, domestic or foreign, relating to in any way the environment, preservation or reclamation
of natural resources, oil pollution, air pollution, water pollution, noise control and/or the
management, release or threatened release, handling, discharge, disposal or recovery of on-site or
off-site asbestos, radioactive materials, spilled or leaked petroleum products, distillates or
fractions and industrial solid waste or hazardous substances as defined by 42 U.S.C. § 9601, et
seq., as amended, as each of the foregoing may be amended from time to time.
Environmental Liability
means any claim, demand, obligation, cause of action, order,
4
violation, damage, injury, judgment, penalty or fine, cost of enforcement, cost of remedial
action or any other costs or expense whatsoever, contingent or otherwise, including reasonable
attorneys fees and disbursements and any liability for cleanups, costs of environmental
remediation, fines or penalties, resulting from the violation or alleged violation of any
Environmental Law or the release of any substance into the environment which is required to be
remediated by a regulatory agency or governmental authority or the imposition of any Environmental
Lien (as hereinafter defined), which could reasonably be expected to individually or in the
aggregate have a Material Adverse Effect.
Environmental Lien
means a Lien in favor of any court, governmental agency or
instrumentality or any other Person (i) for any Environmental Liability or (ii) for damages arising
from or cost incurred by such court or governmental agency or instrumentality or other person in
response to a release or threatened release of asbestos or hazardous substance into the
environment, the imposition of which Lien could reasonably be expected to have a Material Adverse
Effect.
ERISA
means the Employee Retirement Income Security Act of 1974, as amended.
Eurodollar Base Rate
means the offered rate for the period equal to or greater than
the Interest Period for U.S. dollar deposits of not less than $1,000,000 as of 11:00 a.m. City of
London, England time two (2) Business Days prior to the first day of the Interest Period as shown
on the display designated as British Bankers Association Interest Settlement Rates on Telerate
for the purpose of displaying such rate. In the event such rate is not available on Telerate, then
such offered rate shall be the comparable rate designated by Reuters or, if such a comparable rate
is not designated by Reuters, such offered rate shall be otherwise independently determined by
Agent from another alternate, substantially independent source available to Agent (such as, but not
limited to, Bloomberg) or shall be calculated by Agent by substantially similar methodology as that
theretofore used to determine such offered rate.
Eurodollar Loan
means any Loan during any period which bears interest at the
Eurodollar Rate, or which would bear interest at such rate if the Maximum Rate ceiling was not in
effect at a particular time.
Eurodollar Rate
means, with respect to a Eurodollar Loan for the relevant Interest
Period, the sum of the quotient of (A) the Eurodollar Base Rate applicable to such Interest Period,
divided by (B) one minus the Reserve Requirement (expressed as a decimal) applicable to such
Interest Period. The Eurodollar Rate shall be rounded to the next higher multiple of 1/100th of
one percent if the rate is not such a multiple.
Event of Default
is used herein as defined in Section 14 hereof.
Facility Termination Date
means the Maturity Date.
Federal Funds Effective Rate
means, for any day, an interest rate per annum equal to
the weighted average of the rates on overnight Federal funds transactions with members of the
Federal Reserve System arranged by Federal funds brokers on such day, as published for such day
(or, if such day is not a Business Day, for the immediately preceding Business Day) by the Federal
Reserve Bank of New York, or, if such rate is not so published for any day which is a
5
Business Day, the average of the quotations at approximately 10:00 a.m. (Fort Worth, Texas
time) on such day on such transactions received by Agent from three (3) Federal funds brokers of
recognized standing selected by Agent in its sole discretion.
Financial Statements
means balance sheets, income statements, statements of cash flow,
stockholder equity and appropriate footnotes and schedules, prepared in accordance with Accounting
Principles.
Guarantors
means Approach Operating and Approach Delaware.
Indebtedness
with respect to Borrower means as of any date, all liabilities and
contingent liabilities which would be reflected on a balance sheet and related notes thereto of
Borrower prepared as of such date in accordance with the Accounting Principles, including without
limitation: (i) all obligations for money borrowed; (ii) all obligations under conditional sale or
other title retention agreements and all obligations issued or assumed as full or partial payment
for property, whether or not any such obligations represent obligations for borrowed money; (iii)
all indebtedness secured by any lien existing on property owned or acquired by Borrower subject to
any such lien, whether or not the obligations secured thereby shall have been assumed but only to
the extent of the value of the property so secured; (iv) the proportionate share of Borrower in all
obligations, direct or indirect, to any joint venture, partnership or other entity of which
Borrower is a member; (v) all obligations under guaranties, note purchase agreements and other
documents having similar effect; (vi) all obligations for accounts payable or trade credit; (vii)
indebtedness of any joint venture, partnership or other Person for which Borrower is directly or
indirectly liable; (viii) all obligations and indebtedness arising under a Hedge and (ix) all
obligations under capital leases, operating leases or any other leases only to the extent such
leases would be treated as indebtedness in accordance with the Accounting Principles.
Interest Payment Date
means the last day of each calendar quarter in the case of Base
Rate Loans and, in the case of Eurodollar Loans, the last day of the applicable Interest Period,
and if such Interest Period is longer than three (3) months, at three (3) month intervals following
the first day of such Interest Period.
Interest Period
means with respect to any Eurodollar Loan (i) initially, the period
commencing on the date such Eurodollar Loan is made and ending one (1), two (2), three (3) or six
(6) months thereafter as selected by Borrower pursuant to Section 4(a)(ii), and (ii) thereafter,
each period commencing on the day following the last day of the next preceding Interest Period
applicable to such Eurodollar Loan and ending one (1), two (2), three (3) or six (6) months
thereafter, as selected by Borrower pursuant to Section 4(a)(ii); provided, however, that (A) if
any Interest Period would otherwise expire on a day which is not a Business Day, such Interest
Period shall expire on the next succeeding Business Day unless the result of such extension would
be to extend such Interest Period into the next calendar month, in which case such Interest Period
shall end on the immediately preceding Business Day, (B) if any Interest Period begins on the last
Business Day of a calendar month (or on a day for which there is no numerically corresponding day
in the calendar month at the end of such Interest Period) such Interest Period shall end on the
last Business Day of a calendar month, and (iii) any Interest Period which would otherwise expire
after the Maturity Date shall end on such Maturity Date.
6
Letters of Credit
is used herein as defined in Section 2(c) hereof.
Lien
means any mortgage, deed of trust, pledge, security interest, assignment,
encumbrance or lien (statutory or otherwise) of every kind and character.
Loan Documents
means this Agreement, the Notes, the Collateral Documents and all other
documents executed by Borrower with Agent or Lenders in connection with the transaction described
in this Agreement.
Loans
means the Revolving Loans.
Material Adverse Effect
means a material adverse effect on (i) the assets or
properties, liabilities, financial condition, business or operations of Borrower, (ii) the ability
of Borrower to carry out its businesses as of the date of this Agreement or as proposed at the date
of this Agreement to be conducted, (iii) the ability of Borrower to perform fully and on a timely
basis its obligations under any of the Loan Documents, (iv) the validity or enforceability of any
of the Loan Documents or the rights and remedies of Agent or Lenders thereunder or (v) the
Collateral, the Liens on the Collateral created pursuant to the Loan Documents or the priority of
any such Lien.
Maturity Date
means January 31, 2008.
Maximum Rate
is used herein as defined in Section 23 hereof.
Notes
means the Notes, substantially in the form of Exhibit B hereto issued or to be
issued hereunder to each Lender, respectively, to evidence the indebtedness to such Lender arising
by reason of the Advances on the Commitment, together with all modifications, renewals and
extensions thereof or any part thereof.
Oil and Gas Properties
means all oil, gas and mineral properties and interests and
related personal properties, in which Borrower owns an interest.
Payor
is used herein as defined in Section 3(h) hereof.
Permitted Liens
means (i) royalties, overriding royalties, reversionary interests,
production payments and similar burdens; (ii) sales contracts or other arrangements for the sale of
production of oil, gas or associated liquid or gaseous hydrocarbons which would not (when
considered cumulatively with the matters discussed in clause (i) above) deprive Borrower of any
material right in respect of Borrowers assets or properties (except for rights customarily granted
with respect to such contracts and arrangements); (iii) statutory Liens for taxes or other
assessments that are not yet delinquent (or that, if delinquent, are being contested in good faith
by appropriate proceedings, levy and execution thereon having been stayed and continue to be stayed
and for which Borrower has set aside on its books adequate reserves in accordance with Accounting
Principles); (iv) easements, rights of way, servitudes, permits, surface leases and other rights in
respect to surface operations, pipelines, grazing, logging, canals, ditches, reservoirs or the
like, conditions, covenants and other restrictions, and easements of streets, alleys, highways,
pipelines, telephone lines, power lines, railways and other easements and rights of way on, over or
in respect of Borrowers assets or properties and that do not individually or in
7
the aggregate cause a Material Adverse Effect; (v) materialmens, mechanics, repairmans,
employees, vendors, laborers, warehousemens, landlords, carriers, pipelines, contractors,
sub-contractors, operators, non-operators (arising under operating or joint operating
agreements), and other Liens (including any financing statements filed in respect thereof)
incidental to obligations incurred by Borrower in connection with the construction, maintenance,
development, transportation, processing, storage or operation of Borrowers assets or properties to
the extent not delinquent (or which, if delinquent, are being contested in good faith by
appropriate proceedings and for which Borrower has set aside on its books adequate reserves in
accordance with Accounting Principles); (vi) all contracts, agreements and instruments, and all
defects and irregularities and other matters affecting Borrowers assets and properties which were
in existence at the time Borrowers assets and properties were originally acquired by Borrower and
all routine operational agreements entered into in the ordinary course of business, which
contracts, agreements, instruments, defects, irregularities and other matters and routine
operational agreements are not such as to, individually or in the aggregate, interfere materially
with the operation, value or use of Borrowers assets and properties, considered in the aggregate;
(vii) Liens in connection with workmens compensation, unemployment insurance or other social
security, old age pension or public liability obligations; (viii) legal or equitable encumbrances
deemed to exist by reason of the existence of any litigation or other legal proceeding or arising
out of a judgment or award with respect to which an appeal is being prosecuted in good faith and
levy and execution thereon have been stayed and continue to be stayed; (ix) rights reserved to or
vested in any municipality, governmental, statutory or other public authority to control or
regulate Borrowers assets and properties in any manner, and all applicable laws, rules and orders
from any governmental authority; (x) landlords Liens; (xi) Liens incurred pursuant to the
Collateral Documents and Liens that secure obligations under Rate Management Transactions permitted
pursuant to Section 13(f) hereof; (xii) any inconsequential, insignificant or immaterial Liens
against any of the Oil and Gas Properties which do not interfere with or impair Borrowers
ownership of, or right or ability to receive proceeds of production from, such property, and which,
singularly or collectively with other inconsequential, insignificant or immaterial Liens, do not
result in a Material Adverse Effect on Borrower; and (xiii) Liens existing at the date of this
Agreement which are identified in Schedule 1 hereto.
Person
means an individual, a corporation, a partnership, an association, a trust or
any other entity or organization, including a government or political subdivision or an agency or
instrumentality thereof.
Plan
means any plan subject to Title IV of ERISA and maintained by Borrower, or any
such plan to which Borrower is required to contribute on behalf of its employees.
Pre-Approved Contracts
means any contracts or agreements entered into in connection
with any Rate Management Transaction which are designed to hedge, provide a price floor for, or
swap crude oil or natural gas or otherwise sell up to 75%, or in the case of Rate Management
Transactions resulting in a floor price per barrel or mcf, not more than 100% of Borrowers
Projected Production, (with oil and gas calculated separately) for Rate Management Transactions
with Termination Dates of no more than thirty-six (36) months.
Prime Rate
means the rate per annum equal to the Prime Rate announced from time to time by Agent (which is not necessarily the lowest rate charged to any customer), changing when
8
and as said Prime Rate changes.
Projected Production
means the projected production from Borrowers proved developed
producing Oil and Gas Properties as of the date on which any calculation is made as forecasted in
the most recent engineering report provided to Lenders.
Pro Rata or Pro Rata Part
means for each Lender, (i) for all purposes where no Loan is
outstanding, such Lenders Commitment Percentage and (ii) otherwise, the proportion which the
portion of the outstanding Loans owed to such Lender bears to the aggregate outstanding Loans owed
to all Lenders at the time in question.
Rate Management Transaction
means (i) any transaction (including an agreement with
respect thereto) now existing or hereafter entered into by Borrower or any Affiliate which is a
rate swap, basis swap, forward rate transaction, commodity swap, commodity option, equity or equity
index swap, equity or equity index option, bond option, interest rate option, forward exchange
transaction, cap transaction, floor transaction, collar transaction, forward transaction, currency
swap transaction, cross-currency rate swap transaction, currency option or any other similar
transaction (including any option with respect to any of these transactions) or any combination
thereof, whether linked to one or more interest rates, foreign currencies, commodity prices, equity
prices or other financial measures and (ii) any swap, collar, floor, cap, futures or other contract
(including sales contracts with known prices) between Borrower and any Person which is intended to
reduce or eliminate the risk of fluctuations in the price of hydrocarbons, including, without
limitation, the purchase or sale of any hydrocarbons for future delivery, any transaction in a
forward contract for the delivery of any hydrocarbons, any physical or spot transaction in any
hydrocarbons, or any transaction involving the purchase or sale of an option on any of the
foregoing.
Redetermination Date
is used herein as defined in Section 7(b) hereof.
Regulation D
means Regulation D of the Board of Governors of the Federal Reserve
System as from time to time in effect and any successor thereto and other regulation or official
interpretation of said Board of Governors relating to reserve requirements applicable to member
banks of the Federal Reserve System.
Reimbursement Obligations
means, at any time, the obligations of Borrower in respect
of all Letters of Credit then outstanding to reimburse amounts paid by any Lender in respect of any
drawing or drawings under a Letter of Credit.
Release Price
is used herein as defined in Section 12(r) hereof.
Required Lenders
means Lenders holding 66-2/3% or more of the Commitments or if one or
more of the Commitments has been terminated, Lenders holding 66-2/3% of the outstanding Loans.
Required Payment
is used herein as defined in Section 3(h) hereof.
Reserve Requirement
means, with respect to any Interest Period, the maximum aggregate
reserve requirement (including all basic, supplemental, marginal and other reserves) which is
9
imposed under Regulation D on Eurocurrency liabilities.
Revolving Loan or Loans
means an Advance or Advances made pursuant to Section 2(a)
hereof.
Termination Date
means, with respect to any Rate Management Transaction, the date of
expiration of that particular Rate Management Transaction.
Total Outstandings
means the total principal balance outstanding on the Notes at any
time plus (ii) the total face amount of all outstanding Letters of Credit, plus (iii) the total
amount of all unpaid Reimbursement Obligations.
Tranche
means a set of Eurodollar Loans made by Lenders at the same time and for the
same Interest Period.
Unscheduled Redeterminations
means a redetermination of the Borrowing Base made at any
time other than on the dates set for the regular semi-annual redetermination of the Borrowing Base
which are made (i) at the request of Borrower (but only once between Redetermination Dates) or (ii)
at the request of Required Lenders (but only once between Redetermination Dates).
2.
Commitments of Lenders
.
(a)
Terms of Commitment
. On the terms and conditions hereinafter set forth, each
Lender agrees severally to make Advances to Borrower from time to time during the period
beginning on the Effective Date and ending on the Maturity Date in such amounts as Borrower
may request up to an amount not to exceed, in the aggregate principal amount advanced at any
time, its Pro Rata Part of the Available Commitment. Subject to the terms of this
Agreement, Borrower may borrow, repay and reborrow at any time prior to the Maturity Date.
The obligation of Borrower hereunder shall be evidenced by this Agreement and the Notes
issued in connection herewith, said Notes to be as described in Section 3 hereof.
Notwithstanding any other provision of this Agreement, no Advance shall be required to be
made hereunder if any Default or Event of Default (as hereinafter defined) has occurred and
is continuing. Each Advance under the Commitment shall be an aggregate amount of at least
$500,000 or any whole multiples of $100,000 in excess thereof. Irrespective of the face
amount of the Note or Notes, Lenders shall never have the obligation to Advance any amount
or amounts in excess of the Commitment.
(b)
Procedure for Borrowing
. Whenever Borrower desires an Advance under the
Commitment, it shall give Agent telegraphic, telex, facsimile or telephonic notice (Notice
of Borrowing) of such requested Advance, which in the case of telephonic notice, shall be
promptly confirmed in writing. Each Notice of Borrowing shall be in the form of Exhibit A
attached hereto and shall be received by Agent not later than 11:00 a.m. Fort Worth, Texas
time, on (i) the Borrowing Date in the case of the Base Rate Loan, or (ii) three Business
Days prior to any proposed Borrowing Date in the case of Eurodollar Loans. Each Notice of
Borrowing shall specify (i) the Borrowing Date (which shall be a Business Day), (ii) the
principal amount to be borrowed, (iii) the portion of the Advance constituting Base Rate
Loans and/or Eurodollar Loans and (iv) if any portion of the proposed Advance is to
constitute Eurodollar Loans, the initial Interest Period
10
selected by Borrower pursuant to Section 4 hereof to be applicable thereto. Upon receipt of
such Notice, Agent shall advise each Lender thereof; provided, that if Lenders have received
at least one (1) days notice of such Advance prior to funding of a Base Rate Loan, or at
least three (3) days notice of each Advance prior to funding in the case of a Eurodollar
Loan, each Lender shall provide Agent at its office at 777 Main Street, Suite 500, Fort
Worth, Texas, not later than 1:00 p.m., Fort Worth, Texas time, on the Borrowing Date, in
immediately available funds, its Pro Rata share of the requested Advance, but the aggregate
of all such fundings by each Lender shall never exceed such Lenders Commitment. Not later
than 2:00 p.m., Fort Worth, Texas time, on the Borrowing Date, Agent shall make available to
Borrower at the same office, in like funds, the aggregate amount of such requested Advance.
Neither Agent nor any Lender shall incur any liability to Borrower in acting upon any Notice
of Borrowing referred to above which Agent or such Lender believes in good faith to have
been given by a duly authorized officer or other person authorized to borrow on behalf of
Borrower or for otherwise acting in good faith under this Section 2(b). Upon funding of
Advances by Lenders and such funds being made available to Borrower in accordance with this
Agreement, pursuant to any such Notice, Borrower shall have effected Advances hereunder.
(c)
Letters of Credit
. On the terms and conditions hereinafter set forth, Agent
shall from time to time during the period beginning on the Effective Date and ending on the
Maturity Date upon request of Borrower, issue standby and/or commercial Letters of Credit
for the account of Borrower (the Letters of Credit) in such face amounts as Borrower may
request, but not to exceed in the aggregate face amount at any time outstanding ten percent
(10%) of the Borrowing Base then in effect. The face amount of all Letters of Credit issued
and outstanding hereunder shall be considered as Advances on the Commitment for Borrowing
Base purposes and all payments made by Agent on such Letters of Credit shall be considered
as Advances under the Notes. Each Letter of Credit issued for the account of Borrower
hereunder shall (i) be in favor of such beneficiaries as specifically requested by Borrower,
(ii) have an expiration date not exceeding the earlier of (a) one year or (b) the Maturity
Date, (iii) be in a minimum amount of $25,000.00 and (iv) contain such other terms and
provisions as may be reasonable required by issuing Lender. Each Lender (other than Agent)
agrees that, upon issuance of any Letter of Credit hereunder, it shall automatically acquire
a participation in Agents liability under such Letter of Credit in an amount equal to such
Lenders Commitment Percentage of such liability, and each Lender (other than Agent) thereby
shall absolutely, unconditionally and irrevocably assume, as primary obligor and not as
surety, and shall be unconditionally obligated to Agent to pay and discharge when due, its
Commitment Percentage of Agents liability under such Letter of Credit. Borrower hereby
unconditionally agrees to pay and reimburse Agent for the amount of each demand for payment
under any Letter of Credit that is in substantial compliance with the provisions of any such
Letter of Credit at or prior to the date on which payment is to be made by Agent to the
beneficiary thereunder, without presentment, demand, protest or other formalities of any
kind. Upon receipt from any beneficiary of any Letter of Credit of any demand for payment
under such Letter of Credit, Agent shall promptly notify Borrower of the demand and the date
upon which such payment is to be made by Agent to such beneficiary in respect of such
demand. Upon receipt of such notice from Agent,
11
Borrower shall advise Agent whether or not it intends to borrow hereunder to finance its
obligations to reimburse Agent, and if so, submit a Notice of Borrowing as provided in
Section 2(b) hereof. If Borrower fails to so advise Agent and thereafter fails to reimburse
Agent, Agent shall notify each Lender of the demand and the failure of Borrower to reimburse
Agent, and each Lender shall reimburse Agent for its Commitment Percentage of each such draw
paid by Agent and unreimbursed by Borrower. All such amounts paid by Agent and/or
reimbursed by Lenders shall be treated as an Advance or Advances under the Commitment, which
Advances shall be immediately due and payable and shall bear interest at the Maximum Rate.
Borrower agrees to pay Agent for the benefit of Lenders commissions for issuing the Letters
of Credit (calculated separately for each Letter of Credit) in an amount equal to the
greater of (i) $500 or, (ii) one percent (1.00%) of the maximum face amount of the Letter of
Credit. Such commissions will be calculated on the basis of a year consisting of 360 days.
(d)
Procedure for Obtaining Letters of Credit
. The amount and date of issuance,
renewal, extension or reissuance of a Letter of Credit pursuant to the Commitments shall be
designated by Borrowers written request delivered to Agent at least three (3) Business Days
prior to the date of such issuance, renewal, extension or reissuance. Concurrently with or
promptly following the delivery of the request for a Letter of Credit, Borrower shall
execute and deliver to Agent an application and agreement with respect to the Letter of
Credit, said application and agreement to be in the form used by Agent (in the event that
there is any conflict between the terms of any such application and agreement for any Letter
of Credit and this Agreement, the terms of this Agreement shall prevail). Agent shall not
be obligated to issue, renew, extend or reissue any Letter of Credit if (i) the amount
thereon when added to the face amount of the outstanding Letters of Credit plus any
Reimbursement Obligations exceeds ten percent (10%) of the Borrowing Base or (ii) the amount
thereof when added to the Total Outstandings would exceed the Commitment.
(e)
Outstanding Letters of Credit
. On the Effective Date, the Letters of Credit
listed on Schedule 2(e) shall be deemed to have been issued under this Agreement by Agent,
without payment of any fees otherwise due upon the issuance of a Letter of Credit, and Agent
shall be deemed, without further action by any party hereto, to have sold to each Lender,
and each Lender shall be deemed, without further action by any party hereto, to have
purchased from Agent, a participation, to the extent of such Lenders Pro Rata Part, in such
Letters of Credit.
(f)
Voluntary Reduction of Borrowing Base
. Subject to the provisions of Section
5(c) hereof, Borrower may at any time, or from time to time, upon not less than three (3)
Business Days prior written notice to Agent, reduce the Borrowing Base; provided, however,
that (i) each reduction in the Borrowing Base must be in the amount of $1,000,000 or more,
in increments of $1,000,000 and (ii) each reduction must be accompanied by a prepayment of
the Notes in the amount by which the Total Outstandings exceed the Borrowing Base as reduced
pursuant to this Section 2(f).
(g)
Mandatory Borrowing Base Reductions
. The Borrowing Base shall be reduced from
time to time by an amount of any prepayment required by Section 12(r)
12
hereof upon the sale of assets. If, as a result of any such reduction in the Borrowing
Base, the Total Outstandings ever exceed the Borrowing Base then in effect, Borrower shall
make the mandatory prepayment of principal required pursuant to Section 9(b) hereof.
(h)
Several Obligations
. The obligations of Lenders under the Commitments are
several and not joint. The failure of any Lender to make an Advance required to be made by
it shall not relieve any other Lender of its obligation to make its Advance, and no Lender
shall be responsible for the failure of any other Lender to make the Advance to be made by
such other Lender. No Lender shall be required to lend hereunder any amount in excess of
its legal lending limit.
(i)
Type and Number of Advances
. Any Advance on the Commitment may be a Base Rate
Loan or a Eurodollar Loan, or a combination thereof, as selected by Borrower pursuant to
Section 4 hereof. The total number of Tranches which may be outstanding at any time shall
never exceed five (5).
3.
Notes Evidencing Loans
. The loans described above in Section 2 shall be evidenced by promissory
notes of Borrower as follows:
(a)
Form of Notes
. The Loans shall be evidenced by a Note or Notes in the aggregate
face amount of $100,000,000, and shall be in the form of Exhibit B hereto with appropriate
insertions. Notwithstanding the face amount of the Notes, the actual principal amount due
from Borrower to Lenders on account of the Notes, as of any date of computation, shall be
the sum of Advances then and theretofore made on account thereof, less all principal
payments actually received by Lenders in collected funds with respect thereto. Although the
Notes may be dated as of the Effective Date, interest in respect thereof shall be payable
only for the period during which the loans evidenced thereby are outstanding and, although
the stated amount of the Notes may be higher, the Notes shall be enforceable, with respect
to Borrowers obligation to pay the principal amount thereof, only to the extent of the
unpaid principal amount of the Loans. Irrespective of the face amount of the Notes, no
Lender shall ever be obligated to advance on the Commitment any amount in excess of its
Commitment then in effect.
(b)
Issuance of Additional Notes
. At the Effective Date there shall be outstanding
Notes in the aggregate face amount of $100,000,000 payable to the order of
Lenders
.
From time to time new Notes may be issued to other Lenders as such Lenders become parties to
this Agreement. Upon request from Agent, Borrower shall execute and deliver to Agent any
such new or additional Notes. From time to time as new Notes are issued Agent shall require
that each Lender exchange its Note(s) for newly issued Note(s) to better reflect the extent
of each Lenders Commitments hereunder.
(c)
Interest Rates
. The unpaid principal balance of the Notes shall bear interest
from time to time as set forth in Section 4 hereof.
(d)
Payment of Interest
. Interest on the Notes shall be payable on each Interest
Payment Date unless earlier due in whole or in part as a result of an acceleration
13
of the amount due as a result of an Event of Default or pursuant to the mandatory prepayment
provisions of Section 9(b) or 9(c) hereof.
(e)
Payment of Principal
. Principal of the Loans shall be due and payable to Agent
for the
ratable
benefit of Lenders on the Maturity Date unless earlier due in whole
or in part as a result of an acceleration of the amount due or pursuant to the mandatory
prepayment provisions of Section 9(b) or 9(c) hereof.
(f)
Payment to Lenders
. Each Lenders Pro Rata Part of payment or prepayment of the
Loans shall be directed by wire transfer to such Lender by Agent at the address provided to
Agent for such Lender for payments no later than 2:00 p.m., Fort Worth, Texas, time on the
Business Day such payments or prepayments are deemed hereunder to have been received by
Agent; provided, however, in the event that any Lender shall have failed to make an Advance
as contemplated under Section 2 hereof (a Defaulting Lender) and Agent or another Lender
or Lenders shall have made such Advance, payment received by Agent for the account of such
Defaulting Lender or Lenders shall not be distributed to such Defaulting Lender or Lenders
until such Advance or Advances shall have been repaid in full to Lender or Lenders who
funded such Advance or Advances. Any payment or prepayment received by Agent at any time
after 12:00 noon, Fort Worth, Texas, time on a Business Day shall be deemed to have been
received on the next Business Day. Interest shall cease to accrue on any principal as of
the end of the day preceding the Business Day on which any such payment or prepayment is
deemed hereunder to have been received by Agent. If Agent fails to transfer any principal
amount to any Lender as provided above, then Agent shall promptly direct such principal
amount by wire transfer to such Lender.
(g)
Sharing of Payments, Etc
. If any Lender shall obtain any payment (whether
voluntary, involuntary, or otherwise) on account of the Loans (including, without
limitation, any set-off) which is in excess of its Pro Rata Part of payments on the Loans,
as the case may be, obtained by all Lenders, such Lender shall purchase from the other
Lenders such participation as shall be necessary to cause such purchasing Lender to share
the excess payment Pro Rata with each of them; provided that, if all or any portion of such
excess payment is thereafter recovered from such purchasing
Lender
, the purchase
shall be rescinded and the purchase price restored to the extent of the recovery. Borrower
agrees that any Lender so purchasing a participation from another Lender pursuant to this
Section may, to the fullest extent permitted by law, exercise all of its rights of payment
(including the right of offset) with respect to such participation as fully as if such
Lender were the direct creditor of Borrower in the amount of such participation.
(h)
Non-Receipt of Funds by Agent
. Unless Agent shall have been notified by a Lender or
Borrower (the Payor) prior to the date on which such Lender is to make payment to Agent of
the proceeds of a Loan to be made by it hereunder Borrower is to make a payment to Agent for
the account of one or more of Lenders, as the case may be (such payment being herein called
the Required Payment), which notice shall be effective upon receipt, that Payor does not
intend to
make
the Required Payment to Agent, Agent may assume that the Required
Payment has been made and may, in reliance upon such assumption (but shall not be required
to), make the amount thereof available to the intended recipient on such date and, if Payor
has not in fact made the Required
14
Payment to Agent, the recipient of such payment shall, on demand, pay to Agent the amount
made available to it together with interest thereon in respect of the period commencing on
the date such amount was made available by Agent until the date Agent recovers such amount
at the rate applicable to such portion of the applicable Loan.
4.
Interest Rates
.
(a)
Options
.
(i)
Base Rate Loans
. On all Base Rate Loans Borrower agrees to pay
interest on the Notes calculated on the basis of a year consisting of 365 days or
366 days in a leap year, as the case may be, and for the actual number of days
elapsed with respect to the unpaid principal amount of each Base Rate Loan from the
date the proceeds thereof are made available to Borrower until maturity (whether by
acceleration or otherwise), at a varying rate per annum equal to the lesser of (i)
the Maximum Rate, or (ii) the Base Rate plus the Applicable Rate. Subject to the
provisions of this Agreement as to prepayment, the principal of the Notes
representing Base Rate Loans shall be payable as specified in Section 3(e) hereof
and the interest in respect of each Base Rate Loan shall be payable on each Interest
Payment Date applicable thereto. Past due principal and, to the extent permitted by
law, past due interest in respect to each Base Rate Loan, shall bear interest,
payable on demand, at a rate per annum equal to the Default Rate.
(ii)
Eurodollar Loans
. On all Eurodollar Loans Borrower agrees to pay
interest calculated on the basis of a year consisting of 365 days or 366 days in a
leap year, as the case may be, and for the actual number of days elapsed with
respect to the unpaid principal amount of each Eurodollar Loan from the date the
proceeds thereof are made available to Borrower until maturity (whether by
acceleration or otherwise), at a varying rate per annum equal to the lesser of (i)
the Maximum Rate, or (ii) the Eurodollar Rate plus the Applicable Rate. Subject to
the provisions of this Agreement with respect to prepayment, the principal of the
Notes shall be payable as specified in Section 3(e) hereof and the interest with
respect to each Eurodollar Loan shall be payable on each Interest Payment Date
applicable thereto. Past due principal and, to the extent permitted by law, past
due interest shall bear interest, payable on demand, at a rate per annum equal to
the Default Rate. Upon three (3) Business Days written notice prior to the making
by Lenders of any Eurodollar Loan (in the case of the initial Interest Period
therefor) or the expiration date of each succeeding Interest Period (in the case of
subsequent Interest Periods therefor), Borrower shall have the option, subject to
compliance by Borrower with all of the provisions of this Agreement, as long as no
Event of Default exists, to specify whether the Interest Period commencing on any
such date shall be a one (1), two (2), three (3) or six (6) month period, subject to
availability. If Agent shall not have received timely notice of a designation of
such Interest Period as herein provided, Borrower shall be deemed to have elected to
convert all then maturing Eurodollar Loans to Base Rate Loans.
15
(b)
Interest Rate Determination
. Agent shall determine each interest rate
applicable to the Loans hereunder. Agent shall give prompt written notice to Borrower and
Lenders of each rate of interest so determined and its determination thereof shall be
conclusive absent error.
(c)
Conversion Option
. Borrower may elect from time to time (i) to convert all or
any part of its Eurodollar Loans to Base Rate Loans by giving Agent irrevocable notice of
such election in writing prior to 10:00 a.m. (Fort Worth, Texas time) on the conversion date
and such conversion shall be made on the requested conversion date, provided that any such
conversion of a Eurodollar Loan shall only be made on the last day of the Interest Period
with respect thereto, and (ii) to convert all or any part of its Base Rate Loans to
Eurodollar Loans by giving Agent irrevocable written notice of such election no later than
three (3) Business Days prior to the proposed conversion and such conversion shall be made
on the requested conversion date or, if such requested conversion date is not a Business
Day, on the next succeeding Business Day. Any such conversion shall not be deemed to be a
prepayment of any of the loans for purposes of this Agreement or the Notes.
(d)
Recoupment
. If at any time the applicable rate of interest selected pursuant to
Sections 4(a)(i) or 4(a)(ii) above shall exceed the Maximum Rate, thereby causing the
interest on the Notes to be limited to the Maximum Rate, then any subsequent reduction in
the interest rate so selected or subsequently selected shall not reduce the rate of interest
on the Notes below the Maximum Rate until the total amount of interest accrued on the Notes
equals the amount of interest which would have accrued on the Notes if the rate or rates
selected pursuant to Sections 4(a)(i) or (ii), as the case may be, had at all times been in
effect.
(e)
Interest Rates Applicable After Defaul
t. Notwithstanding anything to the
contrary contained in this Section 4, during the continuance of an Event of Default the
Required Lenders may, at their option, by notice from Agent to Borrower (which notice may be
revoked at the option of the Required Lenders notwithstanding the provisions of Section 15
hereof, which requires all Lenders to consent to changes in interest rates) declare that no
Advance may be made as, converted into, or continued as a Eurodollar Loan. During the
continuance of an Event of Default, the Required Lenders, may, at their option, by notice
from Agent to Borrower (which notice may be revoked at the option of Required Lenders
notwithstanding the provisions of Section 15 hereof, which requires all Lenders to consent
to changes in interest rates) declare that (i) each Eurodollar Loan shall bear interest for
the remainder of the applicable Interest Period at the rate otherwise applicable to such
Interest Period plus two percent (2%) per annum and (ii) each Base Rate Loan shall bear
interest at the rate otherwise applicable to such Base Rate Loan plus two percent (2%),
provided that, during the continuance of an Event of Default under Section 14(g) or 14(h),
the interest rate set forth in clauses (i) and (ii) above (the Default Rate) shall be
applicable to all outstanding Loans without any election or action on the part of Agent or
any Lender.
5.
Special Provisions Relating to Loans
.
16
(a)
Unavailability of Funds or Inadequacy of Pricing
. In the event that, in
connection with any proposed Eurodollar Loan, Agent reasonably determines, which
determination shall, absent manifest error, be final, conclusive and binding upon all
parties, due to changes in circumstances since the date hereof, adequate and fair means do
not exist for determining the Eurodollar Rate or such rate will not accurately reflect the
costs to Lenders of funding a Eurodollar Loan for such Interest Period, Agent shall give
notice of such determination to Borrower and Lenders, whereupon, until Agent notifies
Borrower and Lenders that the circumstances giving rise to such suspension no longer exist,
the obligations of Lenders to make, continue or convert Loans into Eurodollar Loans shall be
suspended, and all Loans to Borrower shall be Base Rate Loans during the period of
suspension.
(b)
Change in Laws
. If at any time hereafter any new law or any change in existing
laws or in the interpretation of any new or existing laws shall make it unlawful for any
Lender to make or continue to maintain or fund Eurodollar Loans hereunder, then such Lender
shall promptly notify Borrower in writing and such Lenders obligation to make, continue or
convert Loans into Eurodollar Loans under this Agreement shall be suspended until it is no
longer unlawful for such Lender to make or maintain Eurodollar Loans. Upon receipt of such
notice, Borrower shall either repay the outstanding Eurodollar Loans owed to such Lender,
without penalty, on the last day of the current Interest Periods (or, if any Lender may not
lawfully continue to maintain and fund such Eurodollar Loans, immediately), or Borrower may
convert such Eurodollar Loans at such appropriate time to Base Rate Loans.
(c)
Increased Cost or Reduced Return
.
(i) If, after the date hereof, the adoption of any applicable law, rule, or
regulation, or any change in any applicable law, rule, or regulation, or any change
in the interpretation or administration thereof by any governmental authority,
central bank, or comparable agency charged with the interpretation or administration
thereof, or compliance by any Lender with any request or directive (whether or not
having the force of law) of any such governmental authority, central bank, or
comparable agency:
(A) shall subject such Lender to any tax, duty, or other charge with
respect to any Eurodollar Loans, its Notes, or its obligation to make
Eurodollar Loans, or change the basis of taxation of any amounts payable to
such Lender under this Agreement or its Notes in respect of any Eurodollar
Loan (other than franchise taxes and taxes imposed on or measured by the
overall net income of such Lender);
(B) shall impose, modify, or deem applicable any reserve, special
deposit, assessment, or similar requirement (other than reserve
requirements, if any, taken into account in the determination of the
Eurodollar Rate) relating to any extensions of credit or other assets of, or
any deposits with or other liabilities or commitments of, such Lender,
including the Commitment of such Lender hereunder; or
17
(C) shall impose on such Lender or on the London interbank market any
other condition affecting this Agreement or its Notes or any of such
extensions of credit or liabilities or commitments;
and the result of any of the foregoing is to increase the cost to such Lender of
making, converting into, continuing, or maintaining any Eurodollar Loan or to reduce
any sum received or receivable by such Lender under this Agreement or its Notes with
respect to any Eurodollar Loan, then Borrower shall pay to such Lender on demand
such amount or amounts as will reasonably compensate such Lender for such increased
cost or reduction. If any Lender requests compensation by Borrower under this
Section 5(c)(i), Borrower may, by notice to such Lender (with a copy to Agent),
suspend the obligation of such Lender to make or continue Eurodollar Loans, or to
convert all or part of the Base Rate Loans owing to such Lender to Eurodollar Loans,
until the event or condition giving rise to such request ceases to be in effect (in
which case the provisions of Section 5(c)(i) shall be applicable); provided that
such suspension shall not affect the right of such Lender to receive the
compensation so requested.
(ii) If, after the date hereof, any Lender shall have reasonably determined
that the adoption of any applicable law, rule, or regulation regarding capital
adequacy or any change therein or in the interpretation or administration thereof by
any governmental authority, central bank, or comparable agency charged with the
interpretation or administration thereof, or any request or directive regarding
capital adequacy (whether or not having the force of law) of any such governmental
authority, central bank, or comparable agency, has or would have the effect of
reducing the rate of return on the capital of such Lender or any corporation
controlling such Lender as a consequence of such Lenders obligations hereunder to a
level below that which such Lender or such corporation could have achieved but for
such adoption, change, request, or directive (taking into consideration its policies
with respect to capital adequacy), then from time to time upon demand Borrower shall
pay to such Lender such additional amount or amounts as will reasonably compensate
such Lender for such reduction. If any Lender requests compensation by Borrower
under this Section 5(c)(ii), Borrower may, by notice to such Lender (with a copy to
Agent), suspend the obligation of such Lender to make or continue Eurodollar Loans,
or to convert all or part of the Base Rate Loans owing to such Lender to Eurodollar
Loans, until the event or condition giving rise to such request ceases to be in
effect (in which case the provisions of Section 5(c)(ii) shall be applicable);
provided that such suspension shall not affect the right of such Lender to receive
the compensation so requested.
(iii) Each Lender shall promptly notify Borrower and Agent of any event of
which it has knowledge, occurring after the date hereof, which will entitle such
Lender to compensation pursuant to this Section 5(c) and will designate a separate
lending office, if applicable, if such designation will avoid the need for, or
reduce the amount of, such compensation and will not, in the judgment of such
Lender, be otherwise disadvantageous to it. Any Lender claiming compensation under
this Section 5(c) shall furnish to Borrower and
18
Agent a statement setting forth the additional amount or amounts to be paid to
it hereunder which shall be conclusive in the absence of manifest error. In
determining such amount, such Lender may use any reasonable averaging and
attribution methods.
(iv) Any Lender giving notice to Borrower through Agent pursuant to this
Section 5(c) shall give to Borrower a statement signed by an officer of such Lender
setting forth in reasonable detail the basis for, and the calculation of such
additional cost, reduced payments or capital requirements, as the case may be, and
the additional amounts required to compensate such Lender therefor.
(v) Within five (5) Business Days after receipt by Borrower of any notice
referred to in this Section 5(c), Borrower shall pay to Agent for the account of
Lender issuing such notice such additional amounts as are required to compensate
such Lender for the increased cost, reduced payments or increased capital
requirements identified therein, as the case may be.
(vi) Failure or delay on the part of any Lender to demand compensation pursuant
to this Section shall not constitute a waiver of any such Lenders right to demand
such compensation.
(d)
Discretion of Lender as to Manner of Funding
. Notwithstanding any provisions of
this Agreement to the contrary, each Lender shall be entitled to fund and maintain its
funding of all or any part of its Loan in any manner it sees fit, it being understood,
however, that for the purposes of this Agreement all determinations hereunder shall be made
as if each Lender had actually funded and maintained each Eurodollar Loan through the
purchase of deposits having a maturity corresponding to the last day of the Interest Period
applicable to such Eurodollar Loan and bearing an interest rate at the applicable interest
rate for such Interest Period.
(e)
Breakage Fees
. Without duplication under any other provision hereof, if any
Lender incurs any loss, cost or expense including, without limitation, any loss of profit
and loss, cost, expense or premium reasonably incurred by reason of the liquidation or
re-employment of deposits or other funds acquired by such Lender to fund or maintain any
Eurodollar Loan or the relending or reinvesting of such deposits or amounts paid or prepaid
to Lenders as a result of any of the following events other than any such occurrence as a
result in the change of circumstances described in Sections 5(a) and (b):
(i) any payment, prepayment or conversion of a Eurodollar Loan on a date other
than the last day of its Interest Period (whether by acceleration, prepayment or
otherwise);
(ii) any failure to make a principal payment of a Eurodollar Loan on the due
date thereof, or
(iii) any failure by Borrower to borrow, continue, prepay or convert to a
Eurodollar Loan on the dates specified in a notice given pursuant to Section 2(b) or
4(c) hereof;
19
then Borrower shall pay to such Lender such amount as will reimburse such Lender for such loss,
cost or expense. If any Lender makes such a claim for compensation, it shall furnish to Borrower
and Agent a statement setting forth the amount of such loss, cost or expense in reasonable detail
(including an explanation of the basis for and the computation of such loss, cost or expense) and
the amounts shown on such statement shall be conclusive and binding absent manifest error.
6.
Collateral Security
.
(a) To secure performance by Borrower of its obligations under this Agreement and the
Notes, Borrower shall grant to Agent in its capacity as such Agent under this Agreement for
the ratable benefit of Lenders hereunder, a first priority security interest in and Lien
(and only Lien, except for Permitted Liens) on certain of the Oil and Gas Properties of
Borrower as may be selected by Agent, in its capacity as such Agent under this Agreement,
and the oil, gas and mineral production therefrom or attributable thereto, and in all
operating agreements and oil or gas purchase contracts (now existing or hereafter arising)
relating to such Oil and Gas Properties and in related personal properties, fixtures and
other properties, as evidenced by mortgages, deeds of trust, assignments of production,
security agreements, general security agreements, indentures, and other documents to be
executed by Borrower and delivered to or on behalf of Agent, in its capacity as such Agent
under this Agreement for the ratable benefit of Lenders. Obligations arising from
agreements arising from Rate Management Transactions between Borrower and one or more of
Lenders or an Affiliate of any of Lenders shall be secured by the Collateral covering the
Oil and Gas Properties on a pari passu basis with the indebtedness and obligations of
Borrower under the Loan Documents. Once agreements arising from Rate Management
Transactions involving one or more Lenders, or an Affiliate of any Lender, are entered into,
and pursuant to this provision become secured by the Collateral on a pari passu basis, said
Collateral shall continue to secure such obligations until such agreements are no longer in
force and effect irrespective of whether Lender involved in such agreement ceases to be a
Lender under this Agreement. All Oil and Gas Properties and other collateral in which
Borrower grants or hereafter grants to Agent for the ratable benefit of Lenders, a first and
prior Lien (to the satisfaction of Agent) in accordance with this Section 6, as such
properties and interests are from time to time constituted, are hereinafter collectively
called the Collateral.
(b) The granting and assigning of such security interests and Liens by Borrower shall
be pursuant to Collateral Documents in form and substance reasonably satisfactory to Agent.
Concurrently with the delivery of each of the Collateral Documents or within a reasonable
time thereafter, Borrower shall have furnished or caused to be furnished to Agent mortgage
and title opinions and other title information reasonably satisfactory to Agent with respect
to the title and Lien status of Borrowers interests in not less than 75% of the Engineered
Value of the mortgaged Borrowing Base Properties. Engineered Value for this purpose shall
mean future net revenues discounted at the discount rate being used by Agent as of the date
of any such determination utilizing the pricing parameters used in the engineering report
furnished to Agent pursuant to Sections 7 and 12 hereof. Borrower will cause to be executed
and delivered to Agent, in the future, additional Collateral Documents if Agent reasonably
20
deems such are necessary to insure perfection or maintenance of Lenders security
interests and Liens in not less than 80% of the Engineered Value of Borrowers Oil and Gas
Properties which are included in the Borrowing Base then in effect.
(c) Guarantors shall unconditionally guarantee the Notes pursuant to a guaranty
agreement in form and substance satisfactory to Agent.
7.
Borrowing Base
.
(a)
Initial Borrowing Base
. At the Effective Date, the Borrowing Base shall be
$75,000,000.
(b)
Subsequent Determinations of Borrowing Base
. Subsequent determinations of the
Borrowing Base shall be made by Lenders semi-annually on or before March 1 and September 1
of each year beginning September 1, 2007 (each Redetermination Date) or as Unscheduled
Redeterminations. No later than August 1 of each year (for the September 1 Redetermination
Date of such year) Borrower shall furnish to Lenders an engineering report in form and
substance reasonably satisfactory to Agent prepared by DeGolyer and MacNaughton or such
other independent petroleum engineering firm acceptable to Agent, said engineering report to
utilize economic and pricing parameters used by Agent as established from time to time,
together with such other information, reports and data concerning the value of Borrowing
Base Properties as Agent shall deem reasonably necessary to determine the value of such
Borrowing Base Properties. The engineering report prepared for the September 1
Redetermination Date shall be prepared as of the preceding July 1 of such year and the
engineering report prepared for the March 1 Redetermination Date shall be prepared as of
January 1 of such year. In addition to the scheduled semi-annual Borrowing Base
Redeterminations, Borrower and Lenders may each request one Unscheduled Redetermination
between Redetermination Dates. By February 1 of each year (for the March 1 Redetermination
Date for such year) beginning February 1, 2008, or within thirty (30) days after either (i)
receipt of notice from Agent that Lenders require an Unscheduled Redetermination, or (ii)
Borrower gives notice to Agent of its desire to have an Unscheduled Redetermination
performed, in each case Borrower shall furnish to Lenders an engineering report prepared by
a petroleum engineer employed by Borrower and updating the most recent engineering report
delivered to Lenders hereunder, in form and substance reasonably satisfactory to Agent, said
engineering report to utilize economic and pricing parameters used by Agent as established
from to time, together with such other information, reports and data concerning the value of
such Borrowing Base Properties. Agent shall by written notice to Borrower within a
reasonable time after each Redetermination Date (the date of such notice being herein called
the Determination Date) notify Borrower of the designation by Lenders of the new Borrowing
Base for the period beginning on such Determination Date and continuing until, but not
including, the next Determination Date. If an Unscheduled Redetermination is to be made by
Lenders, Agent shall notify Borrower within a reasonable time after receipt of all requested
information of the new Borrowing Base, and such new Borrowing Base shall continue until the
next Determination Date. If Borrower does not furnish all such information, reports and
data by any date specified in this Section 7(b), unless such failure is of no fault of
Borrower, Lenders nonetheless shall
21
designate the Borrowing Base at any amounts which Lenders in their discretion determine and
redesignate the Borrowing Base from time to time thereafter until Lenders receive all such
information, reports and data, whereupon Lenders shall designate a new Borrowing Base as
described above. The procedure for determining the Borrowing Base at each redetermination
shall be that Agent shall determine the Borrowing Base and submit the same to Lenders.
Increases in the Borrowing Base will require approval of all Lenders, but other
reaffirmations or changes in the Borrowing Base will be subject to the approval of Required
Lenders. The failure of any Lender to respond within fifteen (15) days after receipt of the
proposed Borrowing Base shall be deemed to be an approval of the proposed Borrowing Base.
If Required Lenders (or all Lenders in the case of an increase in the Borrowing Base) do not
approve of Agents proposed Borrowing Base, Agent shall poll Lenders to determine the
highest Borrowing Base that is acceptable to such Lenders that constitute Required Lenders
(or all Lenders in the case of an increase in the Borrowing Base), and such amount shall
then become the new Borrowing Base. Each Lender shall determine the amount of the Borrowing
Base based upon the loan collateral value which such Lender in its sole discretion (using
such methodology, assumptions and discount rates as such Lender customarily uses in
assigning collateral value to Borrowing Base Properties, oil and gas gathering systems, gas
processing and plant operations) assigns to such Borrowing Base Properties of Borrower at
the time in question and based upon such other credit factors consistently applied
(including, without limitation, the assets, liabilities, cash flow, business, properties,
prospects, management and ownership of Borrower and the effect of Rate Management
Transactions in effect at such time) as such Lender customarily considers in evaluating
similar oil and gas credits. If at any time any of the Borrowing Base Properties are sold,
the Borrowing Base then in effect shall automatically be reduced as required by Section
12(r) hereof. It is expressly understood that Lenders have no obligation to designate the
Borrowing Base at any particular amounts, except in the exercise of their discretion,
whether in relation to the Commitments or otherwise. Provided, however, that Lenders shall
not have the obligation to designate a Borrowing Base in an amount in excess of the
Commitment.
8.
Fees
.
(a)
Up-Front Fee
. Upon execution of this Agreement, Borrower shall pay to Agent for
the ratable benefit of Lenders, a fee of $37,500 (calculated as being 25 b.p. times the
increase in the initial Borrowing Base under this Agreement from the Borrowing Base in
effect under the Original Credit Agreement (defined in Section 36 below) as reasonable
compensation to Lenders for making the Loans available to Borrower.
(b)
Unused Commitment Fee
. Borrower shall pay to Agent for the ratable benefit of
Lenders an unused commitment fee (the Unused Commitment Fee) equivalent to the Unused
Commitment Fee Rate times the daily average of the sum of the Borrowing Base minus Total
Outstandings. Such Unused Commitment Fee shall be calculated on the basis of a year
consisting of 360 days. The Unused Commitment Fee shall be payable in arrears on the last
day of each calendar quarter beginning March 31, 2007 with the final fee payment due on the
Maturity Date for any period then ending for which the Unused Commitment Fee shall not have
been theretofore paid. In the event the
22
Commitment terminates on any date prior to the end of any such quarterly period, Borrower
shall pay to Agent for the ratable benefit of Lenders, on the date of such termination, the
total Unused Commitment Fee due for the period in which such termination occurs. If a date
for payment of the Unused Commitment Fee shall be other than a Business Day such payment
shall be made on the next succeeding Business Day.
9.
Prepayments
.
(a)
Voluntary Prepayments
. Subject to the provisions of Section 5(e) hereof,
Borrower may at any time and from time to time, without penalty or premium, prepay the
Notes, in whole or in part. Each such prepayment shall be made on at least three (3)
Business Days notice to Agent in the case of Eurodollar Loan Tranches and without notice in
the case of Base Rate Loans and shall be in a minimum amount of (i) $100,000 or any whole
multiple of $100,000 in excess thereof (or the unpaid balance of the Notes, whichever is
less), for Base Rate Loans, plus accrued interest thereon and (ii) $1,000,000 or any
integral multiple thereof (or the unpaid balance on the Notes, whichever is less) for
Eurodollar Loans, plus accrued interest thereon to the date of prepayment.
(b)
Mandatory Prepayment For Borrowing Base Deficiency
. In the event the Total
Outstandings ever exceed the Borrowing Base as determined by Lenders pursuant to Section
7(b) hereof (a Borrowing Base Deficiency), Borrower shall, within fifteen (15) days after
written notification from Agent, either (i) by instruments reasonably satisfactory in form
and substance to Agent, provide Agent with collateral with value and quality in amounts
satisfactory to all of Lenders in their discretion in order to increase the Borrowing Base
by an amount at least equal to such excess, (ii) prepay, without premium or penalty, the
principal amount of the Notes in an amount at least equal to such excess plus accrued
interest thereon to the date of prepayment or (iii) commit to make six (6) equal monthly
installment payments in the aggregate amount of the Borrowing Base Deficiency, with the
first such installment being due on or before thirty (30) days after Borrowers receipt of
Agents notice of the Borrowing Base Deficiency.
10.
Representations and Warranties
. In order to induce Lenders to enter into this Agreement,
Borrower represents and warrants to Lenders (which representations and warranties will survive the
delivery of the Notes) that:
(a)
Organization and Qualification
. Borrower is a limited partnership duly
organized and validly existing under the laws of the State of Texas and has all limited
partnership power and authority required to own its property and carry on its business as
presently conducted and proposed to be conducted. Each Guarantor is duly organized and
validly existing under the laws of the State of Delaware and has all corporate power and
authority required to own its property and carry on its business as presently conducted and
proposed to be conducted. Approach Operating is authorized to do business in the State of
Texas. Borrower has all power and authority to own its properties and assets and to
transact the business in which it is engaged.
(b)
Power and Authority
. Borrower has the partnership power and requisite authority
to execute, deliver and perform the necessary Loan Documents, including this
23
Agreement; and has taken all partnership action necessary for the due creation and issuance
of the Notes and for the due execution, delivery and performance of the Loan Documents,
including this Agreement. Each Guarantor has the corporate power and requisite authority to
execute, deliver the Loan Documents which it has executed and has taken all company action
necessary to duly authorize (i) the execution, delivery and performance by such Guarantor of
the terms and provisions of the Loan Documents which it has executed and (ii) the
performance by such Guarantor of its obligations under the Loan Documents.
(c)
Binding Obligations
. This Agreement does, and the Notes and other Loan
Documents upon their creation, issuance, execution and delivery will, constitute valid and
binding obligations of Borrower enforceable in accordance with its respective terms (except
that enforcement may be subject to general principles of equity and any applicable
bankruptcy, insolvency, or similar debtor relief laws now or hereafter in effect and
relating to or affecting the enforcement of creditors rights generally).
(d)
No Legal Bar or Resultant Lien
. The Notes and the Loan Documents, including
this Agreement, do not and will not, to the best of Borrowers and each Guarantors
knowledge, violate or conflict with or result in a default under any provisions of
Borrowers organizational documents or any contract, agreement, law, regulation, order,
injunction, judgment, decree or writ to which Borrower or any Guarantor is subject, or
result in the creation or imposition of any Lien or other encumbrance upon any assets or
properties of Borrower or any Guarantor, other than those contemplated by this Agreement.
(e)
No Consent
. The execution, delivery and performance by Borrower of the Notes
and the execution, delivery and performance by Borrower and Guarantors of the other Loan
Documents that each has executed, including this Agreement, does not require the consent or
approval of any other person or entity, including without limitation any regulatory
authority or governmental body of the United States or any state thereof or any political
subdivision of the United States or any state thereof except for consents required for
federal, state and, in some instances, private leases, rights-of-ways and other conveyances
or encumbrances of oil and gas leases all of which shall have been obtained.
(f)
Financial Condition
. The Financial Statements of Borrower and Guarantors which
have been delivered to Lenders pursuant to the terms hereof are complete and correct in all
material respects and fully and accurately reflect in all material respects the financial
conditions and the results of the operations of Borrower and Guarantors as of the dates of
such Financial Statements and no change has occurred between such date and the Effective
Date in the condition, financial or otherwise of Borrower or any Guarantor which is
reasonably expected to have a Material Adverse Effect, except as disclosed to Lenders in
Schedule 2 attached hereto.
(g)
Liabilities
. Neither Borrower nor any Guarantor has any material liability,
direct or contingent on the Effective Date, except as disclosed to Lenders in the Financial
Statements or on Schedule 3 attached hereto. No unusual or unduly burdensome
restrictions, restraint, or hazard exists by contract, law or governmental regulation or
24
otherwise relative to the business, assets or properties of Borrower or any Guarantor which
is reasonably expected to have a Material Adverse Effect or which involve any of the Loan
Documents.
(h)
Litigation
. Except as described in the Financial Statements, or as otherwise
disclosed to Lenders in Schedule 4 attached hereto, on the Effective Date there is no
litigation, legal or administrative proceeding, investigation or other action of any nature
pending or, to the knowledge of Borrower, threatened against or affecting Borrower or any
Guarantor which involves the possibility of any judgment or liability not fully covered by
insurance, and which is reasonably expected to have a Material Adverse Effect.
(i)
Taxes; Governmental Charges
. Borrower and each Guarantor have filed all tax
returns and reports required to be filed and have paid all taxes, assessments, fees and
other governmental charges levied upon Borrower or any Guarantor or Borrowers or any
Guarantors assets, properties or income which are due and payable, including interest and
penalties, the failure of which to pay could reasonably be expected to have a Material
Adverse Effect, except such as are being contested in good faith by appropriate proceedings
and for which adequate reserves for the payment thereof as required by Accounting Principles
has been provided and levy and execution thereon have been stayed and continue to be stayed.
(j)
Titles, Etc
. Borrower has good and defensible title to all of its material
assets, including without limitation, the Oil and Gas Properties, free and clear of all
Liens except Permitted Liens. Borrower is entitled to receive not less than that percentage
of oil, gas and other hydrocarbons produced from the land covered by the leases pertaining
to the Oil and Gas Properties included in the Borrowing Base (after deduction of all
royalties, overriding royalties and other interests payable from or measured by production)
equal to the net revenue interest specified in the evaluation of such Oil and Gas
Properties in the most recent engineering and/or reserve report(s) covering such Oil and Gas
Properties which are delivered to Agent hereunder, with the term net revenue interest
meaning the proportionate share of the production of oil, gas or other minerals to which
Borrower is entitled after deduction of all royalties, overriding royalties and other
interests payable from or measured by production. Borrower owns the working interest in
the Oil and Gas Properties included in the Borrowing Base specified in the evaluation of
such Oil and Gas Properties in the most recent engineering report(s) and/or reserve reports
covering such Oil and Gas Properties which are delivered to Agent hereunder, with the term
working interest, as used herein, meaning the right to explore for, drill and produce oil,
gas or other minerals; and Borrower is not obligated to bear more than that percentage of
the cost of all operations conducted on the Oil and Gas Properties equal to the working
interest as above described (other than increases to Borrowers working interest as a
result of non-operators electing to not participate in a proposed operation under an
operating agreement). All material oil, gas and mineral leases which constitute a portion
of the Oil and Gas Properties are in full force and effect, and Borrower has not defaulted
on any of its obligations thereunder so as to materially impair the value of such leases in
the aggregate.
25
(k)
Defaults
. Neither Borrower nor any Guarantor is in default and no event or
circumstance has occurred which, but for the passage of time or the giving of notice, or
both, would constitute a default under any loan or credit agreement, indenture, mortgage,
deed of trust, security agreement or other agreement or instrument to which Borrower or any
Guarantor is a party in any respect that would be reasonably expected to have a Material
Adverse Effect. No Default or Event of Default hereunder has occurred and is continuing.
(l)
Casualties; Taking of Properties
. Since the dates of the latest Financial
Statements of Borrower and Guarantors delivered to Lenders, neither the business nor the
assets or properties of Borrower or any Guarantor has been affected (to the extent it is
reasonably expected to cause a Material Adverse Effect), as a result of any fire, explosion,
earthquake, flood, drought, windstorm, accident, strike or other labor disturbance, embargo,
requisition or taking of property or cancellation of contracts, permits or concessions by
any domestic or foreign government or any agency thereof, riot, activities of armed forces
or acts of God or of any public enemy.
(m)
Use of Proceeds; Margin Stock
. The proceeds of the Commitment may be used by
Borrower solely for the purposes of (i) refinancing existing indebtedness under the Original
Credit Agreement, (ii) acquisition, exploration and development of Oil and Gas Properties,
including capital expenditures to fund drilling activities on the Oil and Gas Properties,
(iii) working capital; and (iv) other general corporate purposes in the ordinary course of
Borrowers business. Borrower is not engaged principally or as one of its important
activities in the business of extending credit for the purpose of purchasing or carrying any
margin stock as defined in Regulation U of the Board of Governors of the Federal Reserve
System (12 C.F.R. Part 221), or for the purpose of reducing or retiring any indebtedness
which was originally incurred to purchase or carry a margin stock or for any other purpose
which might constitute this transaction a purpose credit within the meaning of said
Regulation U.
Neither Borrower nor any person or entity acting on behalf of Borrower has taken or will take
any action which might cause the loans hereunder or any of the Loan Documents, including this
Agreement, to violate Regulation U or any other regulation of the Board of Governors of the Federal
Reserve System or to violate the Securities Exchange Act of 1934 or any rule or regulation
thereunder, in each case as now in effect or as the same may hereafter be in effect.
(n)
Location of Business and Offices
. The principal place of business and chief
executive office of Borrower is located at the address as stated in Section 17 hereof or
such other places or offices for which notice has been provided to Agent according to
Section 13(f).
(o)
Compliance with the Law
. To the best of Borrowers knowledge, Borrower:
(i) is not in violation of any law, judgment, decree, order, ordinance, or
governmental rule or regulation to which Borrower, or any of its or any Guarantors
assets or properties are subject; or
26
(ii) has not failed to obtain any license, permit, franchise or other
governmental authorization necessary to the ownership of any of its assets or
properties or the conduct of its business;
which violation or failure is reasonably expected to have a Material Adverse Effect.
(p)
No Material Misstatements
. No information, exhibit or report furnished by
Borrower to Lenders in connection with the negotiation of this Agreement contained any
material misstatement of fact or omitted to state a material fact or any fact necessary to
make the statements contained therein not materially misleading.
(q)
Not A Utility
. Neither Borrower nor any Guarantor is a utility subject to
regulation under the laws of the State of Texas as a result of being engaged in the (i)
generation, transmission, or distribution and sale of electric power; (ii) transportation,
distribution and sale through a local distribution system of natural or other gas for
domestic, commercial, industrial, or other use; (iii) provision of telephone or telegraph
service to others; (iv) production, transmission, or distribution and sale of steam or
water; (v) operation of a railroad; or (vi) provision of sewer service to others.
(r)
ERISA
. Borrower maintains no employee benefit plan or other plan for employees
of Borrower that are covered by Title IV of ERISA.
(s) Intentionally Deleted.
(t)
No Subsidiaries
. Borrower has neither formed nor acquired any subsidiaries and,
during the term of the Loan, Borrower shall neither form nor acquire any subsidiary unless
at the time such subsidiary is formed or created, such subsidiary shall unconditionally
guarantee the Notes and the obligations of Borrower under this Agreement pursuant to a
guaranty agreement in form and substance satisfactory to Agent.
(u)
Environmental Matters
. Except as disclosed on Schedule 6, as of the Effective
Date Borrower has not (i) received notice or otherwise learned or is otherwise aware of any
Environmental Liability which would be reasonably expected to individually or in the
aggregate have a Material Adverse Effect arising in connection with (A) any non-compliance
with or violation of the requirements of any Environmental Law or (B) the release or
threatened release of any toxic or hazardous waste into the environment, (ii) received
notice or otherwise become aware of any threatened or actual liability in connection with
the release or notice of any threatened release of any toxic or hazardous waste into the
environment which would be reasonably expected to individually or in the aggregate have a
Material Adverse Effect or (iii) received notice or otherwise learned of or otherwise become
aware of any federal or state investigation evaluating whether any remedial action is needed
to respond to a release or threatened release of any toxic or hazardous waste into the
environment for which Borrower is or may be liable which would reasonably be expected to
result in a Material Adverse Effect.
(v)
Liens
. Except (i) as disclosed on Schedule 1 hereto and (ii) for Permitted
Liens, the assets and properties of Borrower are free and clear of all liens and
27
encumbrances.
(w)
Solvency
. Immediately after the consummation of the transactions to occur on
the Effective Date and immediately following the making of each Loan made on the Effective
Date and after giving effect to the application of the proceeds of such Loans, (i) the fair
value of the assets of Borrower will exceed its debts and liabilities, subordinated,
contingent or otherwise; (ii) the present fair saleable value of the property of Borrower
will be greater than the amount that will be required to pay the probable liability of its
debts and other liabilities, subordinated, contingent or otherwise, as such debts and
liabilities become absolute and matured; (iii) Borrower will be able to pay its debts and
liabilities, subordinated, contingent or otherwise, as such debts and liabilities become
absolute and matured; and (iv) Borrower will not have unreasonably small capital with which
to conduct the business in which it is engaged as such business is now conducted and is
proposed to be conducted following the Effective Date.
(x)
Insurance
. All insurance reasonably necessary in the ordinary course of
Borrowers business is maintained by or on behalf of Borrower and all premiums in respect of
such insurance have been paid or will be paid prior to the date such premium payments are
due.
11.
Conditions of Lending.
(a) The effectiveness of this Agreement, and the obligation to make the initial
Advance under the Commitment shall be subject to satisfaction of the following
conditions precedent:
(i)
Borrowers Execution and Delivery
. Borrower shall have executed
and delivered to Agent the Agreement, the Notes and other required Loan Documents,
all in form and substance satisfactory to Agent;
(ii)
Guaranty
. Guarantors shall have executed an unconditional
guaranty agreement of the Notes in form and substance satisfactory to Agent.
(iii)
Partnership Agreement
. Borrower shall have delivered to Agent a
true and correct copy of the limited partnership agreement of Borrower, together
with all amendments thereto, certified as being a true and correct copy thereof.
(iv)
Partnership Authority Certificate
. Borrower shall have delivered
to Agent a Certificate of Partnership Authority of Borrower, certifying the name,
title and signature of the Person authorized to sign the Loan Documents to which it
is party on behalf of Borrower, duly executed by the partners of Borrower.
(v)
Articles, Bylaws and Regulations
. Borrower shall have delivered to
Agent a true and correct copy of its articles of organization, together with all
amendments thereto. Guarantors shall have delivered to Agent a true and correct
copy of each of their regulations and the articles of incorporation and bylaws of
Approach Resources, together with all amendments thereof, and being certified by the
secretary of each Guarantor and Approach Resources as being a true and
28
correct copy thereof.
(vi)
Resolutions
. Borrower shall have caused to be delivered to Agent
resolutions of the board of directors of Approach Resources and the member of each
Guarantor approving Approach Resources and each Guarantors execution, delivery and
performance of the Loan Documents to which it is a party, duly adopted by such board
of directors, certified by the secretary or member of Approach Resources and each
Guarantor, as being a true and correct copy of such resolutions and that such
resolutions have not been amended or rescinded and remain in full force and effect.
(vii)
Incumbency Certificate
. Agent shall have received a signed
certificate of the secretary or member of Approach Resources and each Guarantor
certifying the name, office and signature of the member or officers of Approach
Resources and each Guarantor authorized to sign the Loan Documents to which it is a
party.
(viii)
Other Certificates
. Agent shall have received certificates of
existence and (in the case of Guarantors and Approach Resources only) of good
standing for Borrower, Approach Resources and each Guarantor issued by the Secretary
of State of Texas (in the case of Borrower) and the Secretary of State of Delaware
(in the case of Guarantors and Approach Resources).
(ix)
Mortgage and Title
. Agent shall have received the mortgage and
title information required to be delivered by Borrower pursuant to Section 6 of this
Agreement;
(x)
Representation and Warranties
. The representations and warranties
of Borrower under this Agreement and the other Loan Documents shall be true and
correct in all material respects as of such date, as if then made (except to the
extent that such representations and warranties related solely to an earlier date);
(xi)
No Event of Default
. No Default or Event of Default shall have
occurred and be continuing;
(xii)
Legal Opinions
. Agent shall have received from Borrowers and
each Guarantors legal counsel one or more favorable legal opinions in form and
substance reasonably satisfactory to Agent.
(xiii)
Other Documents
. Agent shall have received such other
instruments and documents incidental and appropriate to the transaction provided for
herein as Agent or its counsel may reasonably request, and all such documents shall
be in form and substance reasonably satisfactory to Agent; and
(xiv)
Legal Matters Satisfactory
. All legal matters incident to the
consummation of the transactions contemplated hereby shall be reasonably
satisfactory to special counsel for Agent retained at the expense of Borrower.
29
(b) The obligation of Lenders to make any Advance or issue any Letter of Credit under
the Commitment (other than the initial Advance) shall be subject to the following additional
conditions precedent that, at the date of making each such Advance or issuing such Letter of
Credit and after giving effect thereto:
(xv)
Representations and Warranties
. The representations and
warranties of Borrower under this Agreement and the other Loan Documents are true
and correct in all material respects as of such date, as if then made (except to the
extent that such representations and warranties related solely to an earlier date);
and
(xvi)
No Event of Default
. No Default or Event of Default shall have
occurred and be continuing; and
(xvii)
Legal Matters Satisfactory
. All legal matters incident to the
consummation of the transactions contemplated hereby shall be reasonably
satisfactory to special counsel for Agent retained at the expense of Borrower; and
(xviii)
Total Outstandings
. After giving effect to such Advance or
Letter of Credit, the Total Outstandings do not exceed the Borrowing Base then in
effect.
Each Borrowing Notice shall constitute a representation and warranty by Borrower that the
conditions contained in Sections 11(b)(i) and (ii) have been satisfied.
12.
Affirmative Covenants.
A deviation from the provisions of this Section 12 shall not constitute
a Default or an Event of Default under this Agreement if such deviation is expressly consented to
in writing by Required Lenders prior to the date of deviation. Borrower will at all times comply
with the covenants contained in this Section 12 from the date hereof and for so long as the
Commitments are in existence or any amount is owed to Agent or Lenders under this Agreement or the
other Loan Documents.
(a)
Financial Statements and Reports of Borrower, Guarantor
. Borrower shall furnish
to Agent: (i) as soon as available, but in any event within ninety (90) days after the end
of each fiscal year of Borrower and each Guarantor, commencing with the fiscal year ending
December 31, 2006, an audited consolidated balance sheet of Borrower and Guarantors prepared
as of the close of such fiscal year and audited consolidated statements of operations,
changes in partners or shareholders/members equity and statements of cash flows of Borrower
and Guarantors for such year, in each case setting forth in comparative form the figures for
the preceding fiscal year, all in reasonable detail and certified by independent certified
public accountants selected by Borrower and approved by Agent; and (ii) within sixty (60)
days after the end of the first three fiscal quarters of each fiscal year of Borrower and
Guarantors, commencing with the fiscal quarter ending March 30, 2007, an unaudited balance
sheet (without footnotes) of Borrower and Guarantors prepared as of the close of such fiscal
quarter and unaudited statements of operations (without footnotes) of Borrower and
Guarantors for such quarter.
30
(b)
Hedging Report
. Concurrently with the furnishing of the Financial Statements
required in (a) above and in connection with each Borrowing Base redetermination and at any
other time when requested by Agent, Borrower will provide to Agent a hedging report in form
and substance satisfactory to Agent which shall contain, without limitation, the Projected
Production for the latest available calendar quarter with supporting data, a description of
outstanding Rate Management Transactions, including the commodity, effective date,
termination date, notional quantity, applicable price, cap, or floor, and such other details
required by Agent.
(c)
Additional Information
. Promptly upon request of Agent from time to time any
additional financial information or other information that the Agent may reasonably request.
(d)
Certificates of Compliance
. Concurrently with the furnishing of the Financial Statements pursuant to Subsection 12(a)
hereof for the months coinciding with the end of each fiscal year or quarter, Borrower will
furnish or cause to be furnished to Agent a certificate in the form of Exhibit C attached
hereto, signed by the President, Treasurer or Chief Financial Officer of Approach Operating,
as the sole general partner of Borrower, (i) stating that Borrower has fulfilled in all
material respects its obligations under the Notes and the Loan Documents, including this
Agreement, and that all representations and warranties made herein and therein continue
(except to the extent they relate solely to an earlier date) to be true and correct in all
material respects (or specifying the nature of any change), or if a Default has occurred,
specifying the Default and the nature and status thereof, (ii) to the extent requested from
time to time by Agent, specifically affirming compliance of Borrower in all material
respects with any of its representations (except to the extent they relate solely to an
earlier date) or obligations under said instruments; (iii) setting forth the computation, in
reasonable detail as of the end of each period covered by such certificate, of compliance
with Section 13(b); and (iv) containing or accompanied by such financial or other details,
information and material as Agent may reasonably request to evidence such compliance.
(e)
Taxes and Other Liens
. Borrower and each Guarantor will pay and discharge
promptly all taxes, assessments and governmental charges or levies imposed upon Borrower and
such Guarantor, or upon the income or any assets or property of such Borrower, as well as
all claims of any kind (including claims for labor, materials, supplies and rent) which, if
unpaid, might become a Lien or other encumbrance upon any or all of the assets or property
of Borrower or any Guarantor and which could reasonably be expected to result in a Material
Adverse Effect; provided, however, that neither Borrower nor any Guarantor shall be required
to pay any such tax, assessment, charge, levy or claim if the amount, applicability or
validity thereof shall currently be contested in good faith by appropriate proceedings
diligently conducted, levy and execution thereon have been stayed and continue to be stayed
and if Borrower or Guarantors shall have set up adequate reserves therefor, if required,
under Accounting Principles.
(f)
Compliance with Laws
. Borrower and Guarantors will observe and comply, in all
material respects, with all applicable laws, statutes, codes, acts, ordinances, orders,
judgments, decrees, injunctions, rules, regulations, orders and restrictions relating
31
to
environmental standards or controls or to energy regulations of all federal, state, county,
municipal and other governments, departments, commissions, boards, agencies, courts,
authorities, officials and officers, domestic or foreign.
(g)
Further Assurances
. Borrower will cure promptly any defects in the creation and
issuance of the Notes and the execution and delivery of the Notes and the Loan Documents,
including this
Agreement. Borrower at its sole expense will promptly execute and deliver to Agent upon its
reasonable request all such other and further documents, agreements and instruments in
compliance with or accomplishment of the covenants and agreements in this Agreement, or to
correct any omissions in the Notes or more fully to state the obligations set out herein.
(h)
Performance of Obligations
. Borrower will pay the Notes and other obligations
incurred by it hereunder according to the reading, tenor and effect thereof and hereof; and
Borrower and Guarantors will do and perform every act and discharge all of the obligations
provided to be performed and discharged by Borrower and Guarantors under the Loan Documents,
including this Agreement, at the time or times and in the manner specified.
(i)
Insurance
. Borrower now maintains and will continue to maintain insurance with
financially sound and reputable insurers with respect to its assets against such
liabilities, fires, casualties, risks and contingencies and in such types and amounts as is
customary in the case of persons engaged in the same or similar businesses and similarly
situated. Upon request of Agent, Borrower will furnish or cause to be furnished to Agent
from time to time a summary of the respective insurance coverage of Borrower in form and
substance reasonably satisfactory to Agent, and, if requested, will furnish Agent copies of
the applicable policies. Upon demand by Agent any insurance policies covering any such
property shall be endorsed (i) to provide that such policies may not be canceled, reduced or
affected in any manner for any reason without fifteen (15) days prior notice to Agent, (ii)
to provide for insurance against fire, casualty and other hazards normally insured against,
in the amount of the full value (less a reasonable deductible not to exceed amounts
customary in the industry for similarly situated business and properties) of the property
insured, and (iii) to provide for such other matters as Agent may reasonably require.
Borrower shall at all times maintain adequate insurance with respect to all of its other
assets and wells in accordance with prudent business practices.
(j)
Accounts and Records
. Borrower and Guarantors will keep proper books, records
and accounts in which full, true and correct entries will be made of all dealings or
transactions in relation to its business and activities, prepared in a manner consistent
with prior years, subject to changes suggested by Borrowers or Guarantors auditors.
(k)
Right of Inspection
. Borrower and Guarantors will permit, after reasonable
notice to Borrower and Guarantors, any officer, employee or agent of Agent to examine
Borrowers and Guarantors books, records and accounts, and take copies and extracts
therefrom, all at such reasonable times during normal business hours and as often as Lenders
may
reasonably request. Lenders will keep all Confidential Information (as herein defined)
confidential and will not disclose or reveal the Confidential Information
32
or any part
thereof other than (i) as required by law, (ii) to Lenders, and Lenders subsidiaries,
Affiliates, officers, employees, legal counsel and regulatory authorities or advisors to
whom it is necessary to reveal such information for the purpose of effectuating the
agreements and undertakings specified herein or as otherwise required in connection with the
enforcement of Lenders and Agents rights and remedies under the Notes, this Agreement and
the other Loan Documents and (iii) any assignee of or participant in, or any prospective
assignee of or participant in, any Lenders rights or obligations under this Agreement. As
used herein, Confidential Information means information about Borrower or Guarantors
furnished by Borrower or Guarantors, but does not include information (i) which was publicly
known, or otherwise known to Lenders, at the time of the disclosure, (ii) which subsequently
becomes publicly known through no act or omission by Lenders, or (iii) which otherwise
becomes known to Lenders, other than through disclosure by Borrower and Guarantors.
(l)
Notice of Certain Events
. Borrower shall promptly notify Agent if Borrower
learns of the occurrence of (i) any event which constitutes a Default or Event of Default
together with a detailed statement by Borrower of the steps being taken to cure such Default
or Event of Default; (ii) any legal, judicial or regulatory proceedings affecting Borrower
or any Guarantor or any of the assets or properties of Borrower or any Guarantor which, if
adversely determined, could reasonably be expected to have a Material Adverse Effect; (iii)
any dispute between Borrower or any Guarantor and any governmental or regulatory body or any
other Person or entity which, if adversely determined, would reasonably be expected to cause
a Material Adverse Effect; and (iv) any other matter which in Borrowers reasonable opinion
could have a Material Adverse Effect.
(m)
Environmental Reports and Notices
. Borrower will deliver to Agent (i) promptly
upon its becoming available, one copy of each report (other than routine informational
filings) sent by Borrower to any court, governmental agency or instrumentality pursuant to
any Environmental Law, (ii) notice, in writing, promptly upon Borrowers receipt of notice
or otherwise learning of any claim, demand, action, event, condition, report or
investigation indicating any potential or actual liability arising in connection with (x)
the non-compliance with or violation of the requirements of any Environmental Law which
reasonably could be expected to have a Material Adverse Effect; (y) the release or
threatened release of any hazardous substance, toxic or hazardous waste into the environment
which reasonably could be expected to have a Material Adverse Effect or which release
Borrower would have a duty to report to any court or government agency or instrumentality,
or (iii) the existence of any Environmental Lien on any properties or assets of Borrower and
Borrower shall promptly deliver a copy of any such notice to Agent.
(n)
Compliance and Maintenance
. Borrower will, (i) observe and comply in all material respects with all Environmental
Laws; (ii) except as provided in Subsections 12(o) and 12(p) below, maintain the Borrowing
Base Properties and other assets and properties in good and workable condition at all times
and make all repairs, replacements, additions, betterments and improvements to the Borrowing
Base Properties and other assets and properties as are needed and proper so that the
business carried on in
33
connection therewith may be conducted properly and efficiently at all
times in the opinion of Borrower, exercised in good faith; (iii) take or cause to be taken
whatever actions are necessary or desirable to prevent an event or condition of default by
any Borrower under the provisions of any gas purchase or sales contract or any other
contract, agreement or lease comprising a part of the Borrowing Base Properties or other
collateral security hereunder which default could reasonably be expected to result in a
Material Adverse Effect; and (iv) furnish Agent upon request evidence reasonably
satisfactory to Agent that there are no Liens, claims or encumbrances on the Borrowing Base
Properties, except Permitted Liens.
(o)
Operation of Properties
. Except as provided in Subsections 12(p) and (q) below,
Borrower will operate, or cause to be operated, all Borrowing Base Properties in a careful
and efficient manner in accordance with the practice of the industry and in compliance in
all material respects with all applicable laws, rules, and regulations, and in compliance in
all material respects with all applicable proration and conservation laws of the
jurisdiction in which the properties are situated, and all applicable laws, rules, and
regulations, of every other agency and authority from time to time constituted to regulate
the development and operation of the properties and the production and sale of hydrocarbons
and other minerals therefrom; provided, however, that Borrower shall have the right to
contest in good faith by appropriate proceedings, the applicability or lawfulness of any
such law, rule or regulation and pending such contest may defer compliance therewith, as
long as such deferment shall not subject the properties or any part thereof to foreclosure
or loss.
(p)
Compliance with Leases and Other Instruments
. Borrower will pay or cause to be
paid and discharge all rentals, delay rentals, royalties, production payment, and
indebtedness required to be paid by such party (or required to keep unimpaired in all
material respects the rights of such party in Borrowing Base Properties) accruing under, and
perform or cause to be performed in all material respects each and every act, matter, or
thing required of such party by each and all of the assignments, deeds, leases, subleases,
contracts, and agreements in any way relating to such party or any of the Borrowing Base
Properties and do all other things necessary of such party to keep unimpaired in all
material respects the rights of such party thereunder and to prevent the forfeiture thereof
or default thereunder; provided, however, that nothing in this Agreement shall be deemed to
require Borrower to perpetuate or renew any oil and gas lease or other lease by payment of
rental or delay rental or by commencement or continuation of operations nor to prevent
Borrower from abandoning or releasing any oil and gas lease or other lease or well thereon
when, in any of such events, in the opinion of Borrower exercised in good faith, it is not
in the best interest of
Borrower to perpetuate the same.
(q)
Certain Additional Assurances Regarding Maintenance and Operations of
Properties
. With respect to those Borrowing Base Properties which are being operated by
operators other than Borrower, Borrower shall not be obligated to perform any undertakings
contemplated by the covenants and agreement contained in Subsections 12(o) or 12(p) hereof
which are performable only by such operators and are beyond the control of Borrower;
however, Borrower agrees to promptly take, or cause to be taken, all
34
reasonable actions
available under any operating agreements or otherwise to bring about the performance of any
such material undertakings required to be performed thereunder.
(r)
Sale of Certain Assets/Prepayment of Proceeds
. Borrower will immediately pay
over to Agent for the ratable benefit of Lenders as a prepayment of principal on the Notes
and a reduction of the Borrowing Base, an amount equal to 100% of the Release Price from
the sale of Borrowing Base Properties, which sale has been approved in advance by Required
Lenders (provided, however, that approval of Required Lenders shall not be required for the
sales of Borrowing Base Properties aggregating an Engineered Value of ten percent (10%) or
less of the Borrowing Base then in effect during any calendar year). The term Release
Price means the amount by which the Total Outstandings exceed the Borrowing Base after the
Borrowing Base is reduced as a result of the sale of Borrowing Base Properties. Any such
prepayment of principal on the Notes required by this Section 12(r), shall not be in lieu
of, but shall be in addition to, any mandatory prepayment of principal required to be paid
pursuant to Section 9(b) hereof. The Borrowing Base shall be reduced by the amount equal to
the Engineered Value of the Borrowing Base Properties sold according to the most recent
reserve report provided to Lender (as determined by Agent) and, in addition thereto, upon
the sale of any Borrowing Base Properties that require the prior approval of Required
Lenders, if requested by Required Lenders, the Borrowing Base will be redetermined pursuant
to an Unscheduled Redetermination, which redetermination will be in addition to any other
Unscheduled Redetermination that may be requested by Required Lenders.
(s)
Title Matters
. As to any Borrowing Base Properties hereafter mortgaged to
Agent, Borrower will promptly (but in no event more than sixty (60) days following such
mortgaging) furnish, or cause to be furnished to Agent title information reasonably
satisfactory to Agent that is necessary to cause Borrower to be in compliance with its
obligations under Section 12(u) with respect to title information, showing good and
defensible title of Borrower to such Borrowing Base Properties subject only to Permitted
Liens.
(t)
Change of Principal Place of Business
. Borrower shall give Agent at least thirty (30) days prior written notice of its intention
to move its principal place of business and executive offices from the address set forth in
Section 17 hereof
(u)
Additional Collateral
. Borrower agrees to regularly monitor engineering data
covering all producing oil and gas properties and interests owned or acquired by Borrower on
or after the date hereof and to mortgage or cause to be mortgaged such of the same to Agent
for the ratable benefit of Lenders in substantially the form of the Collateral Documents, as
applicable, to the extent that Lenders shall at all times during the existence of the
Commitment be secured by perfected Liens and security interests covering not less than
eighty percent (80%) of the Engineered Value of the Borrowing Base Properties of Borrower.
In addition, Borrower agrees that in connection with the mortgaging of such additional
Borrowing Base Properties, it shall within a reasonable time thereafter, deliver or cause to
be delivered to Agent such mortgage and title opinions and other title information with
respect to the title and Lien status of such Borrowing Base Properties as may be necessary
to maintain at all times a level of such title
35
information (showing good and defensible
title) of not less than seventy-five percent (75%) of the Engineered Value of all Borrowing
Base Properties mortgaged to Agent for the ratable benefit of Lenders.
13.
Negative Covenants.
A deviation from the provisions of this Section 13 shall not constitute an
Event of Default under this Agreement if such deviation is consented to in writing by Required
Lenders prior to the date of deviation. Borrower will at all times comply with the covenants
contained in this Section 13 from the date hereof and for so long as the Commitment is in existence
or any amount is owed to Agent or Lenders under this Agreement or the other Loan Documents.
(a)
Negative Pledge
. Borrower shall not, without the prior written consent of
Required Lenders:
(i) create, incur, assume or permit to exist any Lien, security interest or
other encumbrance on any of its assets or properties except Permitted Liens; or
(ii) during any annual period, sell, convey, exchange, lease or otherwise
dispose of during any annual period any of its Oil and Gas Properties having an
aggregate value as determined in the most recent engineering report delivered to
Agent under Section 7(b) hereof in excess of ten percent (10%) of the Borrowing
Base, excluding (i) obsolete or worn-out equipment and (ii) oil, gas and
hydrocarbons sold in the ordinary course of Borrowers business and (iii) Oil and
Gas Properties that have been given no Engineered Value in the Borrowing Base then
in effect. After a Borrowing Base has been determined, upon the sale of any oil and
gas properties, the Borrowing Base shall be reduced, effective on the date of
consummation of such sale, by an amount which the Required Lenders determine is the
Borrowing Base value last assigned to such oil and gas properties
according to the most recent reserve report or update thereof delivered to
Agent. Agent shall provide Borrower with written notice of the redetermined
Borrowing Base made in accordance with this Section 13(a)(ii), which written notice
shall be sufficient to give effect to such redetermined Borrowing Base without
further amendment to this Agreement.
(b)
Current Ratio
. Borrower will not allow the Current Ratio of Borrower to at any
time be less than 1.0 to 1.0.
(c)
Consolidations and Mergers
. Borrower will not consolidate or merge with or into
any other Person if Borrower is not the surviving entity or, if Borrower is the surviving
entity, such merger or consolidation would cause an Event of Default to occur, or permit any
other Person to consolidate with or merge into it if Borrower is not the surviving entity
or, if Borrower is the surviving entity, such merger or consolidation would cause an Event
of Default to occur or transfer all, or substantially all, of its property.
(d)
Limitation on Additional Indebtednes
s. Borrower will not incur, create, assume
or in any manner become or be liable in respect of any indebtedness, nor will any
36
Borrower
guarantee or otherwise in any manner become or be liable in respect of any indebtedness,
liabilities or other obligations of any other person or entity, whether by agreement to
purchase the indebtedness of any other person or entity or agreement for the furnishing of
funds to any other person or entity through the purchase or lease of goods, supplies or
services (or by way of stock purchase, capital contribution, advance or loan) for the
purpose of paying or discharging the indebtedness of any other person or entity, or
otherwise, except that the foregoing restrictions shall not apply to:
(i) the Notes and Letters of Credit, and any renewal or increase thereof, or
other indebtedness of Borrower outstanding at the Effective Date which has
heretofore disclosed to Lenders in Borrowers Financial Statements or on Schedule
4 hereto; or
(ii) taxes, assessments or other government charges which are not yet due or
are being contested in good faith by appropriate action promptly initiated and
diligently conducted, if such reserve as shall be required by Accounting Principles
shall have been made therefor and levy and execution thereon have been stayed and
continue to be stayed; or
(iii) indebtedness (other than in connection with a loan or lending
transaction) incurred in the ordinary course of business, including, but not limited
to indebtedness for drilling, completing, leasing and reworking oil and gas wells;
or
(iv) obligations under permitted Rate Management Transactions; or
(v) such other indebtedness not to exceed $1,000,000; or
(vi) trade payables and other accrued liabilities that are incurred in the
ordinary course of business; and
(vii) any renewals or extensions of (but, other than in the case of the Notes,
not increases in) any of the foregoing.
(e)
Restricted Payments
. Borrower will not declare or pay any cash dividend or
distribution (whether in cash, securities or other property) purchase, redeem or otherwise
acquire for value any of its stock interest now or hereafter outstanding, return any capital
to its stockholders or make any distribution of its assets to its stockholders as such,
except that, if no Event of Default has occurred and is continuing, Borrower may distribute
to its shareholders an amount equal annually to their tax liability incurred as a result of
their ownership interest in Borrower.
(f)
Rate Management Transactions
. Borrower will not enter into any Rate Management
Transaction, except the foregoing prohibition shall not apply to (i) transactions consented
to in writing by the Required Lenders which are on terms acceptable to the Required Lenders,
or (ii) Pre-Approved Contracts. Once Borrower enters into a Rate Management Transaction,
the terms and conditions of such Rate Management Transaction may not be materially amended
or modified, nor may such Rate
37
Management Transaction be cancelled without Borrower having
given Agent written notice of such amendment, modification or cancellation on the date not
later than three (3) Business Days after the date such action takes place. Borrower further
agrees to give Agent written notice of any bankruptcy, insolvency or similar proceeding
commenced by or against any counterparty to any agreement entered into any such Rate
Management Transaction.
(g)
Certain Transactions
. With respect to its Oil and Gas Properties, Borrower
shall not enter into any transaction with any Affiliate except for transactions with
Affiliates upon terms not less favorable to Borrower than would be obtainable at the time in
comparable transactions of Borrower in arms length dealings with Persons other than
Affiliates.
(h)
Intentionally Deleted
.
(i)
Limitation on Investments and New Businesses
. Borrower shall not engage
directly or indirectly in any new business or make any acquisitions, investments, or
commitments, except such businesses, operations,
acquisitions, or investments which are incidental to or reasonably related to the present
businesses and operations conducted by Borrower and except (i) investment in obligations of
the United States government or any agency thereof or obligations guaranteed by the United
States government having a maturity not in excess of one year, (ii) investments in
certificates of deposit of financially sound commercial Bank having a maturity not in excess
of one year, (iii) investments in commercial paper with a rating of at least Prime 1
according to Moodys Investors Service, Inc., or a similar rating of a comparable or
successor service, having a maturity not in excess of one year.
(j)
Limitation on Credit Extensions
. Borrower shall not extend credit, make
advances or make loans to any Person or entity other than normal and prudent extensions of
credit in the ordinary course of business.
(k)
Fiscal Year
. Borrower shall not change its fiscal year.
(l)
Certain Agreements
. Neither Borrower nor any Guarantor shall enter into any
agreement, which by its terms would expressly restrict its performance of its obligations
pursuant to this Loan Agreement or the other Loan Documents.
(m)
Lines of Business
. Borrower shall not directly or indirectly engage in any
business other than the acquisition, exploration, development, operation, management or
resale of oil, gas and energy properties and the processing, gathering, marketing and
transportation of production therefrom.
14.
Events of Default.
Any one or more of the following events shall be considered an Event of
Default as that term is used herein:
(a) Borrower shall fail to pay when due or declared due the principal of the Notes or
any Reimbursement Obligations with respect to any Letter of Credit, including
38
any payment of
principal required under Section 9(b), and such failure to pay shall continue unremedied for
a period of one (1) day; or
(b) Borrower shall fail to pay when due accrued interest on any of the Notes or any
fees or other amounts payable hereunder or under any other Loan Document and such failure to
pay shall continue unremedied for a period of three (3) days; or
(c) Any representation or warranty made by Borrower under this Agreement, or in any
certificate or statement furnished or made to Lenders pursuant hereto, or in
connection herewith, or in connection with any document furnished hereunder, shall
prove to be untrue in any material respect as of the date on which such representation or
warranty is made (or deemed made), or any representation, statement (including financial
statements), certificate, report or other data furnished or to be furnished or made by
Borrower under any Loan Document, including this Agreement, proves to have been untrue in
any material respect; or
(d) Default shall be made in the due observance or performance of any of the covenants
or agreements of Borrower contained in the Loan Documents, including this Agreement
(excluding covenants contained in Section 13 of the Agreement for which there is no cure
period), and such default shall continue for more than thirty (30) days after written notice
from Agent is received by Borrower; or
(e) Default shall be made in the due observance or performance of the covenants of
Borrower contained in Section 13 of this Agreement; or
(f) Default shall be made in respect of any obligation for borrowed money in excess of
$500,000 other than the Notes, for which Borrower is liable (directly, by assumption, as
guarantor or otherwise), or any obligations secured by any mortgage, pledge or other
consensual security interest with respect thereto, on any asset or property of Borrower or
in respect of any agreement relating to any such obligations, and if such default shall
continue beyond the applicable grace period, if any; or
(g) Borrower or any Guarantor shall commence a voluntary case or other proceeding
seeking liquidation, reorganization or other relief with respect to its debts under any
bankruptcy, insolvency or other similar law now or hereafter in effect or seeking an
appointment of a trustee, receiver, liquidator, custodian or other similar official of it or
any substantial part of its property, or shall consent to any such relief or to the
appointment of or taking possession by any such official in an involuntary case or other
proceeding commenced against it, or shall make a general assignment for the benefit of
creditors, or shall fail generally to pay its debts as they become due, or shall take any
corporate action authorizing the foregoing; or
(h) An involuntary case or other proceeding, shall be commenced against Borrower or any
Guarantor seeking liquidation, reorganization or other relief with respect to its debts
under any bankruptcy, insolvency or similar law now or hereafter in effect or seeking the
appointment of a trustee, receiver, liquidator, custodian or other similar official of it or
any substantial part of its property, and such involuntary case or other
39
proceeding shall
remain undismissed and unstayed for a period of sixty (60) days; or an order for relief
shall be entered against Borrower or any Guarantor under the federal bankruptcy laws as now
or hereinafter in effect; or
(i) A final judgment or order for the payment of money in excess of $500,000 (or
judgments or orders aggregating in excess of $500,000) shall be rendered against Borrower
and such judgments or orders shall continue unsatisfied and unstayed for a period of thirty
(30) days; provided, however, that if any such judgment order is not satisfied or stayed
within such 30-day period an Event of Default shall not exist if prior to
the end of such 30-day period Borrower provides to Agent an unqualified statement from
Borrowers insurance carrier addressed to Agent that the entire amount of such judgment or
order is a covered loss under the insurance policies that Borrower maintains with such
insurance carrier and that such insurance carrier does not dispute such insurance coverage
and will provide Borrower with such proceeds of insurance required to satisfy such judgment
or order; or
(j) Borrower shall fail to pay any obligation owed under any Rate Management
Transaction in an amount in excess of $500,000 or in any amount if the obligations of
Borrower under any such Rate Management Transaction are secured by the Collateral Documents
or any event of default (as defined therein) shall occur as a result of the action or
inaction of Borrower under any agreement entered into in connection with any Rate Management
Transaction; or
(k) The Liens securing the Loans cease to be in place and/or effective (other than as a
result of Agents actions or inactions); or
(l) A Change of Control shall occur; or
(m) The dissolution of Borrower or any Guarantor.
Upon occurrence of any Event of Default specified in Subsections 14(g) and (h) hereof, the
entire principal amount due under the Notes and all interest then accrued thereon, and any other
liabilities of Borrower hereunder, shall become automatically and immediately due and payable all
without notice and without presentment, demand, protest, notice of protest or dishonor or any other
notice of default of any kind, all of which are hereby expressly waived by Borrower. Upon the
occurrence of any other Event of Default, Agent, upon request of Required Lenders, shall by written
notice to Borrower terminate the Commitment and declare the principal of, and all interest then
accrued on, the Notes and any other liabilities hereunder to be forthwith due and payable,
whereupon the same shall forthwith become due and payable without presentment, demand, protest,
notice of intent to accelerate, notice of acceleration or other notice of any kind, all of which
Borrower hereby expressly waives, anything contained herein or in the Notes to the contrary
notwithstanding.
Upon the occurrence and during the continuance of any Event of Default, Lenders are hereby
authorized at any time and from time to time, without notice to Borrower (any such notice being
expressly waived by Borrower), to set-off and apply any and all deposits (general or special, time
or demand, provisional or final) at any time held and other indebtedness at any time
40
owing by any Lender to or for the credit or the account of Borrower against any and all of the indebtedness of
Borrower under the Notes and the Loan Documents, including this Agreement, irrespective of whether
or not Lenders shall have made any demand under the Loan Documents, including this Agreement or the
Notes and although such indebtedness may be unmatured. Any amount set-off by any Lender shall be
applied against the indebtedness owed Lenders by Borrower pursuant to this Agreement and the Notes.
Lenders agree promptly to notify Borrower after any such setoff and application, provided that the
failure to give such notice shall not affect the validity of such set-off and application. The
rights of Lenders under this Section are in addition to other rights and remedies (including,
without limitation, other rights of set-off) which Lenders may have.
15.
Agent and Lenders.
(a)
Appointment and Authorization
. Each Lender hereby appoints Agent as its nominee
and agent, in its name and on its behalf: (i) to act as nominee for and on behalf of such
Lender in and under all Loan Documents; (ii) to arrange the means whereby the funds of
Lenders are to be made available to Borrower under the Loan Documents; (iii) to take such
action as may be requested by any Lender under the Loan Documents (when such Lender is
entitled to make such request under the Loan Documents); (iv) to receive all documents and
items to be furnished to Lenders under the Loan Documents; (v) to be the secured party,
mortgagee, beneficiary, and similar party in respect of, and to receive, as the case may be,
any collateral for the benefit of Lenders; (vi) to promptly distribute to each Lender all
material information, requests, documents and items received from Borrower under the Loan
Documents; (vii) to promptly distribute to each Lender such Lenders Pro Rata Part of each
payment or prepayment (whether voluntary, as proceeds of insurance thereon, or otherwise) in
accordance with the terms of the Loan Documents and (viii) to deliver to the appropriate
Persons requests, demands, approvals and consents received from Lenders. Each Lender hereby
authorizes Agent to take all actions and to exercise such powers under the Loan Documents as
are specifically delegated to Agent by the terms hereof or thereof, together with all other
powers reasonably incidental thereto. With respect to its Commitment hereunder and the
Notes issued to it, Agent and any successor Agent shall have the same rights under the Loan
Documents as any other Lender and may exercise the same as though it were not Agent; and the
term Lender or Lenders shall, unless otherwise expressly indicated, include Agent and
any successor Agent in its capacity as a Lender. Agent and any successor Agent and its
Affiliates may accept deposits from, lend money to, act as trustee under indentures of and
generally engage in any kind of business with Borrower, and any person which may do business
with Borrower, all as if Agent and any successor Agent was not Agent hereunder and without
any duty to account therefor to Lenders; provided that, if any payments in respect of any
property (or the proceeds thereof) now or hereafter in the possession or control of Agent
which may be or become security for the obligations of Borrower arising under the Loan
Documents by reason of the general description of indebtedness secured or of property
contained in any other agreements, documents or instruments related to any such other
business shall be applied to reduction of the obligations of Borrower arising under the Loan
Documents, then each Lender shall be entitled to share in such application according to its
Pro Rata Part thereof. Each Lender, upon request of any other Lender, shall disclose to all
other Lenders all
41
indebtedness and liabilities, direct and contingent, of Borrower to such
Lender as of the time of such request.
(b)
Note Holders
. From time to time as other Lenders become a party to this
Agreement, Agent shall obtain execution by Borrower of additional Notes in amounts
representing the Commitments of each such new Lender, up to an aggregate face amount of all
Notes not exceeding $100,000,000. The obligation of such Lender shall be governed by the provisions
of this Agreement, including but not limited to, the obligations specified in Section 2
hereof. From time to time, Agent may require that Lenders exchange their Notes for newly
issued Notes to better reflect the Commitments of Lenders. Agent may treat the payee of any
Note as the holder thereof until written notice of transfer has been filed with it, signed
by such payee and in form satisfactory to Agent.
(c)
Consultation with Counsel
. Lenders agree that Agent may consult with legal
counsel selected by Agent and shall not be liable for any action taken or suffered in good
faith by it in accordance with the advice of such counsel.
LENDERS ACKNOWLEDGE THAT MURPHY
MAHON KEFFLER & FARRIER, L.L.P. IS COUNSEL FOR FROST, BOTH AS AGENT AND AS A LENDER, AND
THAT SUCH FIRM DOES NOT REPRESENT ANY OF THE OTHER LENDERS IN CONNECTION WITH THIS
TRANSACTION.
(d)
Documents
. Agent shall not be under a duty to examine or pass upon the
validity, effectiveness, enforceability, genuineness or value of any of the Loan Documents
or any other instrument or document furnished pursuant thereto or in connection therewith,
and Agent shall be entitled to assume that the same are valid, effective, enforceable and
genuine and what they purport to be.
(e)
Resignation or Removal of Agent
. Subject to the appointment and acceptance of a
successor Agent as provided below, Agent may resign at any time by giving written notice
thereof to Lenders and Borrower, and Agent may be removed at any time with or without cause
by Required Lenders (excluding Agent). If no successor Agent has been so appointed by
Required Lenders (and approved by Borrower) and has accepted such appointment within thirty
(30) days after the retiring Agents giving of notice of resignation or removal of the
retiring Agent, then the retiring Agent may, on behalf of Lenders, appoint a successor
Agent. Any successor Agent must be approved by Borrower, which approval will not be
unreasonably withheld. Upon the acceptance of any appointment as Agent hereunder by a
successor Agent, such successor Agent shall thereupon succeed to and become vested with all
the rights and duties of the retiring Agent, and the retiring Agent, as the case may be,
shall be discharged from its duties and obligations hereunder. After any retiring Agents
resignation or removal hereunder as Agent, the provisions of this Section 15 shall continue
in effect for its benefit in respect to any actions taken or omitted to be taken by it while
it was acting as Agent. To be eligible to be an Agent hereunder the party serving, or to
serve, in such capacity must own a Pro Rata Part of the Commitments equal to the level of
Commitment required to be held by any Lender pursuant to Section 29 hereof.
42
(f)
Responsibility of Agent
. It is expressly understood and agreed that the obligations of Agent under the Loan
Documents are only those expressly set forth in the Loan Documents as to each and that Agent
shall be entitled to assume that no Default or Event of Default has occurred and is
continuing, unless Agent has actual knowledge of such fact or has received notice from a
Lender or Borrower that such Lender or Borrower considers that a Default or an Event of
Default has occurred and is continuing and specifying the nature thereof. Neither Agent nor
any of its directors, officers, attorneys or employees shall be liable for any action taken
or omitted to be taken by them under or in connection with the Loan Documents, except for
its or their own gross negligence or willful misconduct. Agent shall not incur liability
under or in respect of any of the Loan Documents by acting upon any notice, consent,
certificate, warranty or other paper or instrument believed by it to be genuine or authentic
or to be signed by the proper party or parties, or with respect to anything which it may do
or refrain from doing in the reasonable exercise of its judgment, or which may seem to it to
be necessary or desirable.
Agent shall not be responsible to Lenders for any of Borrowers recitals, statements,
representations or warranties contained in any of the Loan Documents, or in any certificate or
other document referred to or provided for in, or received by any Lender under, the Loan Documents,
or for the value, validity, effectiveness, genuineness, enforceability or sufficiency of any of the
Loan Documents or for any failure by Borrower to perform any of its obligations hereunder or
thereunder. Agent may employ agents and attorneys-in-fact and shall not be answerable, except as
to money or securities received by it or its authorized agents, for the negligence or misconduct of
any such agents or attorneys-in-fact selected by it with reasonable care.
The relationship between Agent and each Lender is only that of agent and principal and has no
fiduciary aspects. Nothing in the Loan Documents or elsewhere shall be construed to impose on
Agent any duties or responsibilities other than those for which express provision is therein made.
In performing its duties and functions hereunder, Agent does not assume and shall not be deemed to
have assumed, and hereby expressly disclaims, any obligation or responsibility toward or any
relationship of agency or trust with or for Borrower or any of its beneficiaries or other
creditors. As to any matters not expressly provided for by the Loan Documents, Agent shall not be
required to exercise any discretion or take any action, but shall be required to act or to refrain
from acting (and shall be fully protected in so acting or refraining from acting) upon the
instructions of all Lenders and such instructions shall be binding upon all Lenders and all holders
of the Notes; provided, however, that Agent shall not be required to take any action which is
contrary to the Loan Documents or applicable law.
Agent shall have the right to exercise or refrain from exercising, without notice or liability
to Lenders, any and all rights afforded to Agent by the Loan Documents or which Agent may have as a
matter of law; provided, however, Agent shall not (i) except as provided herein and in Section 7(b)
hereof, without the consent of Required Lenders approve the sale, release or substitution of
Collateral other than the sale of Collateral permitted pursuant to Section 13(a)(ii) hereof, or
(ii) without the consent of Required Lenders, take any other action with regard to amending the
Loan Documents, waiving any Default under the Loan Documents, or taking any other action with
respect to the Loan Documents. Agent shall not have liability to Lenders for failure or delay in
exercising any right or power possessed by Agent pursuant to the Loan
43
Documents or otherwise unless such failure or delay is caused by the gross negligence of
Agent, in which case only Agent responsible for such gross negligence shall have liability therefor
to Lenders.
(g)
Independent Investigation
. Each Lender severally represents and warrants to
Agent that it has made its own independent investigation and assessment of the financial
condition and affairs of Borrower in connection with the making and continuation of its
participation hereunder and has not relied exclusively on any information provided to such
Lender by Agent in connection herewith, and each Lender represents, warrants and undertakes
to Agent that it shall continue to make its own independent appraisal of the
creditworthiness of Borrower while the Notes are outstanding or its commitments hereunder
are in force. Agent shall not be required to keep itself informed as to the performance or
observance by Borrower of this Agreement or any other document referred to or provided for
herein or to inspect the properties or books of Borrower. Other than as provided in this
Agreement, Agent shall not have any duty, responsibility or liability to provide any Lender
with any credit or other information concerning the affairs, financial condition or business
of Borrower which may come into the possession of Agent.
(h)
Indemnification
. Lenders agree to indemnify Agent, its Affiliates, its
directors, officers, attorneys and employees (the Indemnified Agents), from and against
any and all liabilities, obligations, losses, damages, penalties, actions, judgments, suits,
costs, expenses or disbursements of any proper and reasonable kind or nature whatsoever
which may be imposed on, incurred by or asserted against Agent in any way relating to or
arising out of the Loan Documents or any action taken or omitted by any Indemnified Agent
under the Loan Documents, provided that no Lender shall be liable for any portion of such
liabilities, obligations, losses, damages, penalties, actions, judgments, suits, costs,
expenses or disbursements resulting from any Indemnified Agents gross negligence or willful
misconduct. Each Lender shall be entitled to be reimbursed by any such Indemnified Agent
for any amount such Lender paid to such Indemnified Agent under this Section 15(h) to the
extent such Indemnified Agent has been reimbursed for such payments by Borrower or any other
Person.
THE PARTIES INTEND FOR THE PROVISIONS OF THIS SECTION TO APPLY TO AND PROTECT AGENT
FROM THE CONSEQUENCES OF ANY LIABILITY INCLUDING STRICT LIABILITY IMPOSED OR THREATENED TO
BE IMPOSED ON ANY INDEMNIFIED AGENT AS WELL AS FROM THE CONSEQUENCES OF ITS OWN NEGLIGENCE,
WHETHER OR NOT THAT NEGLIGENCE IS THE SOLE, CONTRIBUTING OR CONCURRING CAUSE OF ANY SUCH
LIABILITY.
(i)
Benefit of Section 15
. The agreements contained in this Section 15 are solely
for the benefit of Agent and Lenders and are not for the benefit of, or to be relied upon by, Borrower, any affiliate of
Borrower or any other person.
(j)
Pro Rata Treatment
. Subject to the provisions of this Agreement, each payment
(including each prepayment) by Borrower and each collection by Lenders (including offsets)
on account of the principal of and interest on the Notes and fees
44
provided for in this Agreement, that are payable by Borrower, shall be made Pro Rata; provided, however, in the
event that any Defaulting Lender shall have failed to make an Advance as contemplated under
Section 2 hereof and Agent or another Lender or Lenders shall have made such Advance,
payment received by Agent for the account of such Defaulting Lender or Lenders shall not be
distributed to such Defaulting Lender or Lenders until such Advance or Advances shall have
been repaid in full to the Lender or Lenders who funded such Advance or Advances.
(k)
Assumption as to Payments
. Except as specifically provided herein, unless Agent
shall have received notice from Borrower prior to the date on which any payment is due to
Lenders hereunder that Borrower will not make such payment in full, Agent may, but shall not
be required to, assume that Borrower has made such payment in full to Agent on such date and
Agent may, in reliance upon such assumption, cause to be distributed to each Lender on such
due date an amount equal to the amount then due such Lender. If and to the extent Borrower
shall not have so made such payment in full to Agent, each Lender shall repay to Agent
forthwith on demand such amount distributed to such Lender together with interest thereon,
for each day from the date such amount is distributed to such Lender until the date such
Lender repays such amount to Agent, at the interest rate applicable to such portion of the
Loan.
(l)
Other Financings
. Without limiting the rights to which any Lender otherwise is
or may become entitled, such Lender shall have no interest, by virtue of this Agreement or
the Loan Documents, in (a) any present or future loans from, letters of credit issued by, or
leasing or other financial transactions by, any other Lender to, on behalf of, or with
Borrower (collectively referred to herein as Other Financings) other than the obligations
hereunder; (b) any present or future guarantees by or for the account of Borrower which are
not contemplated by the Loan Documents; (c) any present or future property taken as security
for any such Other Financings; or (d) any property now or hereafter in the possession or
control of any other Lender which may be or become security for the obligations of Borrower
arising under any loan document by reason of the general description of indebtedness secured
or property contained in any other agreements, documents or instruments relating to any such
Other Financings.
(m)
Interests of Lenders
. Nothing in this Agreement shall be construed to create a partnership or joint venture
between Lenders for any purpose. Agent, Lenders and Borrower recognize that the respective
obligations of Lenders under the Commitments shall be several and not joint and that neither
Agent nor any of Lenders shall be responsible or liable to perform any of the obligations of
the other under this Agreement. Each Lender is deemed to be the owner of an undivided
interest in and to all rights, titles, benefits and interests belonging and accruing to
Agent under the Security Instruments, including, without limitation, liens and security
interests in any collateral, fees and payments of principal and interest by Borrower under
the Commitments on a Pro Rata basis. Each Lender shall perform all duties and obligations
of Lenders under this Agreement in the same proportion as its ownership interest in the
Loans outstanding at the date of determination thereof.
(n)
Investments
. Whenever Agent in good faith determines that it is uncertain
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about how to distribute to Lenders any funds which it has received, or whenever Agent in good
faith determines that there is any dispute among Lenders about how such funds should be
distributed, Agent may choose to defer distribution of the funds which are the subject of
such uncertainty or dispute. If Agent in good faith believes that the uncertainty or
dispute will not be promptly resolved, or if Agent is otherwise required to invest funds
pending distribution to Lenders, Agent may invest such funds pending distribution (at the
risk of Lenders). All interest on any such investment shall be distributed upon the
distribution of such investment and in the same proportions and to the same Persons as such
investment. All monies received by Agent for distribution to Lenders (other than to the
Person who is Agent in its separate capacity as a Lender) shall be held by Agent pending
such distribution solely as Agent for such Lenders, and Agent shall have no equitable title
to any portion thereof.
(o)
Delegation to Affiliates
. Borrower and Lenders agree that Agent may delegate
any of its duties under this Agreement to any of its Affiliates. Any such Affiliate (and
such Affiliates directors, officers, agents and employees) which perform duties in
connection with this Agreement shall be entitled to the same benefits of the
indemnification, waiver and other protective provisions to which Agent is entitled under
Sections 15 and 18.
(p)
Execution of Collateral Documents
. Lenders hereby empower and authorize Agent
to execute and deliver the Security Instruments and all related financing statements and
other financing statements, agreements, documents or instruments that shall be necessary or
appropriate to effect the purposes of the Security Instruments.
(q)
Collateral Releases
. Lenders hereby empower and authorize Agent to execute and
deliver to Borrower on its behalf any agreements, documents, or instruments as shall be necessary or appropriate to
reflect any releases of Collateral which shall be permitted by the terms hereof (including,
without limitation, the release of Collateral that Borrower is permitted to sell pursuant to
Section 13 hereof) or of any other Loan Document or which shall otherwise have been approved
by the Required Lenders pursuant to Section 15 hereof.
16.
Exercise of Rights.
No failure to exercise, and no delay in exercising, on the part of Agent
or Lenders, any right hereunder shall operate as a waiver thereof, nor shall any single or partial
exercise thereof preclude any other or further exercise thereof or the exercise of any other right.
The rights of Agent and Lenders hereunder shall be in addition to all other rights provided bylaw.
17.
Notices.
Any notices or other communications required or permitted to be given by this
Agreement or any other documents or instruments referred to herein must be given in writing (which
may be by bank wire, telecopy or similar writing) and shall be given to the party to whom such
notice or communication is directed at the address or telecopy number of such party as follows: (a)
BORROWER: Approach Resources I, LP, 6300 Ridglea Place, Suite 1107, Fort Worth, Texas 76116,
Attention: J. Ross Craft, Facsimile No. (817) 989-9001; with copy to: Steve Smart, 6300 Ridglea
Place, Suite 1107, Fort Worth, Texas 76116, Facsimile No. (817) 989-9001; (b) AGENT and LENDERS:
c/o The Frost National Bank, 777 Main Street, Suite
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500, Fort Worth, Texas 76102, Attention: John S. Warren, Facsimile No. (817) 420-5250. Any such notice or other communication shall be effective
(a) if given by telecopy, when such telecopy is transmitted to the telecopy number specified in
this Section 17 and the appropriate answer back is received or receipt is otherwise confirmed, (b)
if given by mail, three (3) days after deposit in the mails with first-class postage, prepaid, as
addressed as aforesaid or (c) if given by any other method, when delivered at the address specified
in this Section 17; provided, however, that notices to Agent under Sections 2, 3, 4 or 5 hereof
shall not be effective until received. Any notice required to be given to Lenders shall be given
to Agent and distributed to all Lenders by Agent.
18.
Expenses.
Borrower shall pay (i) all reasonable and necessary out-of-pocket expenses of Agent,
including reasonable fees and disbursements of special counsel for Agent, in connection with the
preparation of this Agreement, any waiver or consent hereunder or any amendment hereof or any
Default or Event of Default or alleged Default or Event of Default hereunder, (ii) all reasonable
and necessary out-of-pocket expenses of Agent, including reasonable fees and disbursements of
special counsel for Agent in connection with the preparation of any participation agreement for a
participant or participants requested by Borrower or any amendment thereof and (iii) if a Default
or an Event of Default occurs, all reasonable and necessary out-of-pocket expenses incurred by
Lenders, including reasonable fees and disbursements of counsel, in connection with such Default
and Event of Default and collection and other enforcement proceedings resulting therefrom.
BORROWER HEREBY ACKNOWLEDGES THAT MURPHY MAHON KEFFLER & FARRIER, L.L.P. IS SPECIAL COUNSEL TO
FROST, AS AGENT AND AS A LENDER, UNDER THIS AGREEMENT AND THAT IT IS NOT COUNSEL TO,
NOR DOES IT REPRESENT BORROWER IN CONNECTION WITH THE TRANSACTIONS DESCRIBED IN THIS AGREEMENT.
Borrower is relying on separate counsel in the transaction described herein. Borrower shall
indemnify Lenders, within thirty (30) days after written demand therefor, against any transfer
taxes, document taxes, assessments or charges made by any governmental authority and paid by
Lenders (or Agent on behalf of Lenders) by reason of the execution, delivery and filing of the Loan
Documents. The obligations of this Section 18 shall survive any termination of this Agreement, the
expiration of the Loans and the payment of all indebtedness of Borrower to Lenders hereunder and
under the Notes.
19.
Indemnity.
Borrower hereby agrees to indemnify Agent, each Lender, their respective
Affiliates, and each of their directors, officers, and employees (the Indemnified Parties)
against all losses, claims, damages, penalties, judgments, liabilities and expenses (including,
without limitation, all expenses of litigation or preparation therefor of any Indemnified Party,
Agent, any Lender or any Affiliate that is a party thereto) which any of them may pay or incur
arising out of or relating to this Agreement, the other Loan Documents, the transactions
contemplated hereby or the direct or indirect application or proposed application of the proceeds
of any loan hereunder even if any of the foregoing arises out of the ordinary negligence of the
party seeking indemnification except to the extent that they are determined in a final
non-appealable judgment by a court of competent jurisdiction to have resulted from the gross
negligence or willful misconduct of the party seeking indemnification. The indemnity set forth
herein shall be in addition to any other obligations or liabilities of Borrower to any Indemnified
Party, Agent, and each of Lenders hereunder or at common law or otherwise, and shall survive any
termination of this Agreement, the expiration of the Loans and the payment of
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all indebtedness of Borrower to Lenders hereunder and under the Notes.
THE PARTIES INTEND FOR THE PROVISIONS OF THIS
SECTION TO APPLY TO AND PROTECT EACH INDEMNIFIED PARTY FROM THE CONSEQUENCES OF ANY LIABILITY
INCLUDING STRICT LIABILITY IMPOSED OR THREATENED TO BE IMPOSED ON AGENT AS WELL AS FROM THE
CONSEQUENCES OF ITS OWN NEGLIGENCE, WHETHER OR NOT THAT NEGLIGENCE IS THE SOLE, CONTRIBUTING, OR
CONCURRING CAUSE OF ANY CLAIM.
20.
Non-Liability of Lenders.
The relationship between Borrower on the one hand and Lenders and
Agent on the other hand shall be solely that of borrower and lender. Neither Agent, nor any Lender
shall have any fiduciary responsibility to Borrower. Neither Agent, nor any Lender undertakes any
responsibility to Borrower to review or inform Borrower of any matter in connection with any phase
of Borrowers businesses or operations. Borrower agrees that neither Agent, nor any Lender shall
have any liability to Borrower (whether sounding in tort, contract or otherwise) for losses
suffered by Borrower in connection with, arising out of, or in any way related to, the transactions
contemplated and the relationship established by this Agreement and the other Loan Documents, or
any act, omission or event occurring in connection therewith, unless it is determined in a final
non-appealable judgment by a court of competent jurisdiction that such loss resulted from the gross
negligence or willful misconduct of the party from which recovery is sought. Neither Agent, nor
any Lender shall have any liability with respect to, and Borrower
hereby waives, releases and agrees not to sue for, any special, indirect, consequential or punitive
damages suffered by Borrower in connection with, arising out of, or in any way related to this
Agreement, the Loan Documents or any transaction contemplated thereby.
21.
Governing Law.
THIS AGREEMENT IS BEING EXECUTED AND DELIVERED, AND IS INTENDED TO BE
PERFORMED, IN FORT WORTH, TARRANT COUNTY, TEXAS, AND THE SUBSTANTIVE LAWS OF TEXAS SHALL GOVERN THE
VALIDITY, CONSTRUCTION, ENFORCEMENT AND INTERPRETATION OF THIS AGREEMENT AND ALL OTHER DOCUMENTS
AND INSTRUMENTS REFERRED TO HEREIN, UNLESS OTHERWISE SPECIFIED THEREIN.
22.
Invalid Provisions.
If any provision of this Agreement is held to be illegal, invalid, or
unenforceable under present or future laws effective during the term of this Agreement, such
provisions shall be fully severable and this Agreement shall be construed and enforced as if such
illegal, invalid or unenforceable provision had never comprised a part of this Agreement, and the
remaining provisions of the Agreement shall remain in full force and effect and shall not be
affected by the illegal, invalid or unenforceable provision or by its severance from this
Agreement.
23.
Maximum Interest Rate.
Regardless of any provisions contained in this Agreement or in any
other documents and instruments referred to herein, Lenders shall never be deemed to have
contracted for or be entitled to receive, collect or apply as interest on the Notes any amount in
excess of the Maximum Rate, and in the event any Lender ever receives, collects or applies as
interest any such excess, or if an acceleration of the maturities of any Notes or if any prepayment
by Borrower results in Borrower having paid any interest in excess of the Maximum Rate, such amount
which would be excessive interest shall be applied to the reduction
48
of the unpaid principal balance of the Notes for which such excess was received, collected or applied, and, if the principal
balance of such Note is paid in full, any remaining excess shall forthwith be paid to Borrower.
All sums paid or agreed to be paid to Lenders for the use, forbearance or detention of the
indebtedness evidenced by the Notes and/or this Agreement shall, to the extent permitted by
applicable law, be amortized, prorated, allocated and spread throughout the full term of such
indebtedness until payment in full so that the rate or amount of interest on account of such
indebtedness does not exceed the Maximum Rate. In determining whether or not the interest paid or
payable under any specific contingency exceeds the Maximum Rate of interest permitted by law,
Borrower and Lenders shall, to the maximum extent permitted under applicable law, (i) characterize
any non-principal payment as an expense, fee or premium, rather than as interest; and (ii) exclude
voluntary prepayments and the effect thereof; and (iii) compare the total amount of interest
contracted for, charged or received with the total amount of interest which could be contracted
for, charged or received throughout the entire contemplated term of the Note at the Maximum Rate.
For purposes of Section 303 of the Texas Finance Code, to the extent applicable to any
Lender or Agent, Borrower agrees that the Maximum Rate shall be the weekly ceiling as
defined in said Chapter, provided that such Lender or Agent, as applicable, may also rely, to the
extent permitted by applicable laws of the State of Texas and the United States of America, on
alternative maximum rates of interest under the Texas Finance Code or other laws applicable to such
Lender or Agent from time to time if greater (the Maximum Rate).
24.
Amendments.
This Agreement may be amended only by an instrument in writing executed by an
authorized officer of the party against whom such amendment is sought to be enforced. No
modification or waiver of any provision of the Loan Documents, including this Agreement, or the
Notes nor consent to departure therefrom, shall be effective unless in writing signed by Borrower
and Required Lenders; provided, however, that no amendment, waiver, or other action shall be
effected pursuant to this Section 24 without the consent of all Lenders which: (a) would increase
the Borrowing Base, (b) would reduce any fees hereunder, or the principal of, or the interest on,
any Lenders Note or Notes, (c) would postpone any date fixed for any payment of any fees
hereunder, or any principal or interest of any Lenders Note or Notes, (d) would increase the
aggregate Commitments or any Lenders individual Commitment hereunder or would materially alter
Agents obligations to any Lender hereunder, (e) would release Borrower from its obligation to pay
any Lenders Note or Notes, (f) would release any Collateral (other than the Collateral that is
sold or transferred with the prior consent of Required Lenders pursuant to Section 13(a)(ii)), (g)
would change the definition of Required Lenders (or without the prior consent of Required Lenders
if such consent is not required), or (h) would amend this sentence. No such consent or waiver
shall extend beyond the particular case and purpose involved. No notice or demand given in any
case shall constitute a waiver of the right to take other action in the same, similar or other
circumstances without such notice or demand. No amendment of any provision of this Agreement
relating to Agent shall be effective without the written consent of Agent.
25.
Multiple Counterparts.
This Agreement may be executed in a number of identical separate
counterparts, each of which for all purposes is to be deemed an original, but all of which shall
constitute, collectively, one agreement. No party to this Agreement shall be bound hereby until a
counterpart of this Agreement has been executed by all parties hereto.
49
Delivery of an executed counterpart of a signature page of the Agreement by telecopy shall be effective as delivery of a
manually executed counterpart of this Agreement.
26.
Conflict.
In the event any term or provision hereof is inconsistent with or conflicts with any
provision of the Loan Documents, the terms or provisions contained in this Agreement shall be
controlling.
27.
Survival.
All covenants, agreements, undertakings, representations and warranties made in the
Loan Documents, including this Agreement, the Notes or other documents and instruments referred to
herein shall survive all closings hereunder and shall not be affected by any investigation made by
any party.
28.
Parties Bound.
This Agreement shall be binding upon and inure to the benefit of the parties
hereto and their respective successors and assigns, provided, however, that Borrower may not,
without the prior written consent of all of Lenders, assign any rights, powers, duties or
obligations hereunder.
29.
Assignments and Participations
.
(a) Each Lender shall have the right to sell, assign or transfer all or any part of its
Note or Notes, its Commitment and its rights and obligations hereunder to one or more
Affiliates, Lenders, financial institutions, pension plans, insurance companies, investment
funds, or similar Persons who are Eligible Assignees or to a Federal Reserve Bank; provided,
that each sale, assignment or transfer (other than to an Affiliate or a Federal Reserve
Bank) shall require the consent of Agent and Borrower, which consents will not be
unreasonably withheld; provided, however, that if an Event of Default has occurred and is
continuing, the consent of Borrower shall not be required. Any such assignee, transferee or
recipient shall have, to the extent of such sale, assignment, or transfer, the same rights,
benefits and obligations as it would if it were such Lender and a holder of such Note,
Commitment and rights and obligations, including, without limitation, the right to vote on
decisions requiring consent or approval of all Lenders or Required Lenders and the
obligation to fund its Commitment; provided, that (1) each such sale, assignment, or
transfer (other than to an Affiliate or a Federal Reserve Bank) shall be in an aggregate
principal amount not less than $5,000,000, (2) each remaining Lender shall at all times
maintain Commitment then outstanding in an aggregate principal amount of at least equal to
$5,000,000; (3) each such sale, assignment or transfer shall be of a Pro Rata Part of such
Lenders Commitment, (4) no Lender may offer to sell its Note or Notes, Commitment, rights
and obligations or interests therein in violation of any securities laws; and (5) no such
assignments (other than to a Federal Reserve Bank) shall become effective until the
assigning Lender and its assignee delivers to Agent and Borrower an Assignment and
Acceptance and the Note or Notes subject to such assignment and other documents evidencing
any such assignment. An assignment fee in the amount of $3,500 for each such assignment
(other than to an Affiliate, a Lender or the Federal Reserve Bank) will be payable by the
transferring Lender to Agent by assignor or assignee. Within five (5) Business Days after
its receipt of copies of the Assignment and Acceptance and the other documents relating
thereto and the Note or Notes, Borrower shall execute and deliver to Agent (for delivery to
the relevant assignee) a new Note or
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Notes evidencing such assignees assigned Commitment
and if the assignor Lender has retained a portion of its Commitment, a replacement Note in
the principal amount of the Commitment retained by the assignor (except as provided in the
last sentence of this paragraph (a) such Note or Notes to be in exchange for, but not in
payment of, the Note or Notes held by such Lender). On and after the effective date of an
assignment hereunder, the assignee shall for all purposes be a Lender, party to this
Agreement and any other Loan Document executed by Lenders and shall have all the rights and
obligations of a Lender under the Loan Documents, to the same extent as if it were an
original party thereto, and no further consent or action by Borrower, Lenders or Agent shall
be required to release the transferor Lender with respect to its Commitment assigned to such
assignee and the transferor Lender shall henceforth be so released.
(b) Each Lender shall have the right to grant participations in all or any part of such
Lenders Notes and Commitment hereunder to one or more pension plans, investment funds,
insurance companies, financial institutions or other Persons, provided, that:
(i) each Lender granting a participation shall retain the right to vote
hereunder, and no participant shall be entitled to vote hereunder on decisions
requiring consent or approval of Lender or Required Lenders (except as set forth in
(iii) below);
(ii) in the event any Lender grants a participation hereunder, such Lenders
obligations under the Loan Documents shall remain unchanged, such Lender shall
remain solely responsible to the other parties hereto for the performance of such
obligations, such Lender shall remain the holder of any such Note or Notes for all
purposes under the Loan Documents, and Agent, each Lender and Borrower shall be
entitled to deal with the Lender granting a participation in the same manner as if
no participation had been granted; and
(iii) no participant shall ever have any right by reason of its participation
to exercise any of the rights of Lenders hereunder, except that any Lender may agree
with any participant that such Lender will not, without the consent of such
participant (which consent may not be unreasonably withheld) consent to any
amendment or waiver requiring approval of all Lenders.
(c) It is understood and agreed that any Lender may provide to assignees and
participants and prospective assignees and participants financial information and reports
and data concerning Borrowers properties and operations which was provided to such Lender
pursuant to this Agreement, provided, that each recipient thereto has first agreed, for the
benefit of Borrower, to hold such information, reports and data in confidence on the terms
set out in Section 12(j) hereof.
(d) Upon the reasonable request of either Agent or Borrower, each Lender will identify
those to whom it has assigned or participated any part of its Notes and Commitment, and
provide the amounts so assigned or participated.
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30.
Choice
of Forum: Consent to Service of Process and Jurisdiction.
THE OBLIGATIONS OF
BORROWER UNDER THE LOAN DOCUMENTS ARE PERFORMABLE IN TARRANT COUNTY, TEXAS. ANY SUIT, ACTION OR
PROCEEDING AGAINST BORROWER WITH RESPECT TO THE LOAN DOCUMENTS OR ANY JUDGMENT ENTERED BY ANY COURT
IN RESPECT THEREOF, MAY BE BROUGHT IN THE COURTS OF THE STATE OF TEXAS, COUNTY OF TARRANT, OR IN
THE UNITED STATES COURTS LOCATED IN TARRANT COUNTY, TEXAS AND BORROWER HEREBY SUBMITS TO THE
NON-EXCLUSIVE JURISDICTION OF SUCH COURTS FOR THE PURPOSE OF ANY SUCH SUIT, ACTION OR PROCEEDING.
BORROWER HEREBY IRREVOCABLY CONSENTS TO SERVICE OF PROCESS IN ANY SUIT, ACTION OR PROCEEDING IN
SAID COURT BY THE MAILING THEREOF BY LENDER BY REGISTERED OR CERTIFIED MAIL, POSTAGE PREPAID, TO
BORROWER, AT THE ADDRESS FOR NOTICES AS PROVIDED IN SECTION 17. BORROWER HEREBY IRREVOCABLY WAIVES
ANY OBJECTION WHICH IT MAY NOW OR HEREAFTER HAVE TO THE LAYING OF VENUE OF ANY SUIT, ACTION OR
PROCEEDING ARISING OUT OF OR RELATING TO ANY LOAN DOCUMENT BROUGHT IN THE COURTS LOCATED IN THE
STATE OF TEXAS, COUNTY OF TARRANT, AND HEREBY FURTHER IRREVOCABLY WAIVES ANY CLAIM THAT ANY SUCH
SUIT, ACTION OR PROCEEDING BROUGHT IN ANY SUCH COURT HAS BEEN BROUGHT IN AN INCONVENIENT FORUM.
31.
Waiver of Jury Trial.
BORROWER, AGENT AND LENDERS HEREBY WAIVE, TO THE FULLEST EXTENT
PERMITTED BY APPLICABLE LAW, ANY AND ALL RIGHT TO TRIAL BY JURY IN ANY LEGAL PROCEEDING ARISING OUT
OF OR RELATED TO THIS AGREEMENT OR THE TRANSACTIONS CONTEMPLATED HEREBY.
32.
Other Agreements.
THIS WRITTEN CREDIT AGREEMENT AND THE OTHER LOAN DOCUMENTS REPRESENT THE
FINAL AGREEMENT AMONG THE PARTIES AND MAY NOT BE CONTRADICTED BY EVIDENCE OF PRIOR,
CONTEMPORANEOUS, OR SUBSEQUENT ORAL AGREEMENTS OF THE PARTIES. THERE ARE NO UNWRITTEN ORAL
AGREEMENTS AMONG THE PARTIES.
33.
Financial Terms.
All accounting terms used in this Agreement which are not specifically
defined herein shall be construed in accordance with Accounting Principles.
34.
Tri-Party Loan.
Texas Finance Code, Section 346 shall not apply to loans evidenced by this
Agreement or the Notes.
35.
USA Patriot Act Notice.
Each Lender hereby notifies Borrower that pursuant to the
requirements of the USA Patriot Act (Title III of Pub. L. 107-56 (signed into law October 26,
2001)) (the Act), it is required to obtain, verify and record information that identifies
Borrower, which information includes the name and address of Borrower and other information that
will allow such Lender to identify Borrower in accordance with the Act.
36.
Original Credit Agreement.
Effective upon the Effective Date, this Agreement shall supersede
in its entirety the Credit Agreement dated November 23, 2004 between Borrower
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and Frost (as
amended, the Original Credit Agreement); provided, however, that all loans, letters of credit,
and other indebtedness, obligations and liabilities outstanding under the Original Credit Agreement
on such date shall continue to constitute Loans, Letters of Credit and other indebtedness,
obligations and liabilities under this Agreement and the execution and delivery of this Agreement
or any of the Loan Documents hereunder shall not constitute a novation, refinancing or any other
fundamental change in the relationship among the parties and the Loans, Letters of Credit, and
other indebtedness, obligations and liabilities outstanding hereunder, to the extent outstanding
under the Original Credit Agreement immediately prior to the date hereof, shall constitute the same
loans, letters of credit, and other indebtedness, obligations and liabilities as outstanding under
the Original Credit Agreement.
IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be duly executed as of
the day and year first above written.
[Signature Pages to Follow]
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BORROWER:
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APPROACH RESOURCES I, LP,
a Texas limited partnership
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By:
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Approach Operating, LLC,
a Delaware limited liability company,
its general partner
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By:
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Approach Resources Inc.,
a Delaware corporation, its sole member
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By:
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/s/ J. Ross Craft
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J. Ross Craft, President
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AGENT
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THE FROST NATIONAL BANK
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By:
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/s/ John S. Warren
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John S. Warren, Senior Vice President
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LENDERS
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Commitment Percentage
50%
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THE FROST NATIONAL BANK
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By:
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/s/ John S. Warren
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John S. Warren, Senior Vice President
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Commitment Percentage
50%
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JPMORGAN CHASE BANK, NA
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By:
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/s/ Wm. Mark Cranmer
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Wm. Mark Cranmer, Senior Vice President
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EXHIBIT A
NOTICE OF BORROWING
The undersigned APPROACH RESOURCES I, LP, a Texas limited partnership (Borrower), is
authorized to execute this Notice of Borrowing in the capacity stated below. With reference to
that certain Amended and Restated Credit Agreement dated as of
February ___, 2007 (as same may be
amended, modified, increased, supplemented and/or restated from time to time, the Agreement)
entered into by and among Borrower and THE FROST NATIONAL BANK (Agent), and the financial
institutions parties thereto (the Lenders), Borrower further certifies, represents and warrants
that all of the foregoing statements are true and correct (each capitalized term used herein having
the same meaning given to it in the Agreement unless otherwise specified):
(a) Borrower requests that Lenders advance Borrower on the Loan the aggregate sum of $
by no later than
. Immediately following such Advance, the aggregate outstanding balance of
Advances shall equal $
on the Loan.
(b)
This Advance shall be a: Base Rate Loan
, or a Eurodollar Loan
, (if Eurodollar
please state requested Interest Period
months).
(c) As of the date hereof, and as a result of the making of the requested Advance,
there does not and will not exist any Default or Event of Default.
(d) Borrower has performed and complied in all material respects with all agreements
and conditions contained in the Agreement which are required to be performed or complied
with by Borrower before or on the date hereof.
(e) The representations and warranties contained in the Agreement are true and correct
in all material respects as of the date hereof and shall be true and correct in all material
respects upon the making of the Advance, with the same force and effect as though made on
and as of the date hereof and thereof (except to the extent such representations and
warranties related solely to an earlier date).
(f) No change that would cause a Material Adverse Effect to the condition, financial or
otherwise, of Borrower has occurred since the most recent Financial Statement provided to
Lenders.
1
EXECUTED AND DELIVERED this
day of
, 200 ___.
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APPROACH RESOURCES I, LP,
a Texas limited partnership
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By:
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Approach Operating, LLC,
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a Delaware limited liability company,
its general partner
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By:
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Approach Resources Inc.,
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a Delaware corporation, its sole member
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By:
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J. Ross Craft, President
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2
EXHIBIT B
REVOLVING NOTE
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$100,000,000.00
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Fort Worth, Texas
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February ___, 2007
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FOR VALUE RECEIVED, the undersigned APPROACH RESOURCES I, LP, a Texas limited partnership
(Borrower), hereby unconditionally promises to pay to the order of THE FROST NATIONAL BANK and
the other financial institutions named in the Credit Agreement (as hereinafter defined) (the
Lenders) at the offices of THE FROST NATIONAL BANK (the Agent) in Tarrant County, Texas, the
principal sum of ONE HUNDRED MILLION AND NO/100 DOLLARS ($100,000,000.00), or so much thereof as
may be advanced and outstanding at any time or from time to time pursuant to the Credit Agreement
in lawful money of the United States of America together with interest from the date hereof until
paid at the rates specified in the Credit Agreement. All payments of principal and interest due
hereunder are payable at the offices of Agent at 777 Main Street,
Suite ____, Fort Worth, Texas 76102,
Attention: John S. Warren, or at such other address as Agent shall designate in writing to
Borrower.
The principal and all accrued interest on this Note shall be due and payable in accordance
with the terms and provisions of the Credit Agreement.
This Note is executed pursuant to that certain Credit Agreement (the Credit Agreement) dated
of even date herewith by and among Borrower, the Agent and Lenders, and is one of the Notes
referred to therein. Reference is made to the Credit Agreement and the Loan Documents (as that
term is defined in the Credit Agreement) for a statement of prepayment rights and obligations of
Borrower, for a statement of the terms and conditions under which the due date of this Note may be
accelerated and for statements regarding other matters affecting this Note (including without
limitation the obligations of the holder hereof to advance funds hereunder, principal and interest
payment due dates, voluntary and mandatory prepayments, exercise of rights and remedies, payment of
attorneys fees, court costs and other costs of collection and certain waivers by Borrower and
others now or hereafter obligated for payment of any sums due hereunder). Upon the occurrence of
an Event of Default (as that term is defined in the Credit Agreement and Loan Documents) the Agent
may declare forthwith to be entirely and immediately due and payable the principal balance hereof
and the interest accrued hereon, and the Lender shall have all rights and remedies of the Lender
under the Credit Agreement and Loan Documents. This Note may be prepaid in accordance with the
terms and provisions of the Credit Agreement.
Regardless of any provision contained in this Note, the holder hereof shall never be entitled
to receive, collect or apply, as interest on this Note, any amount in excess of the Maximum Rate
(as such term is defined in the Credit Agreement), and, if the holder hereof ever receives,
collects, or applies as interest any such amount which would be excessive interest, it shall be
deemed a partial prepayment of principal and treated hereunder as such; and, if the indebtedness
evidenced hereby is paid in full, any remaining excess shall forthwith be paid to Borrower. In
determining whether or not the interest paid or payable under any specific contingency exceeds the
Maximum Rate, Borrower and the holder hereof shall, to the maximum extent permitted under
applicable law (i) characterize any non-principal payment as an expense,
1
fee or premium rather than as interest, (ii) exclude voluntary prepayments and the effects
thereof, and (iii) spread the total amount of interest throughout the entire contemplated term of
the obligations evidenced by this Note and/or referred to in the Credit Agreement so that the
interest rate is uniform throughout the entire term of this Note; provided that, if this Note is
paid and performed in full prior to the end of the full contemplated term thereof and if the
interest received for the actual period of existence thereof exceeds the Maximum Rate, the holder
hereof shall refund to Borrower the amount of such excess or credit the amount of such excess
against the indebtedness evidenced hereby, and, in such event, the holder hereof shall not be
subject to any penalties provided by any laws for contracting for, charging, taking, reserving or
receiving interest in excess of the Maximum Rate.
If any payment of principal or interest on this Note shall become due on a day other than a
Business Day (as such term is defined in the Credit Agreement), such payment shall be made on the
next succeeding Business Day and such extension of time shall in such case be included in computing
interest in connection with such payment.
If this Note is placed in the hands of an attorney for collection, or if it is collected
through any legal proceeding at law or in equity or in bankruptcy, receivership or other court
proceedings, Borrower agrees to pay all costs of collection, including, but not limited to, court
costs and reasonable attorneys fees.
Borrower and each surety, endorser, guarantor and other party ever liable for payment of any
sums of money payable on this Note, jointly and severally waive presentment and demand for payment,
notice of intention to accelerate the maturity, protest, notice of protest and nonpayment, as to
this Note and as to each and all installments hereof, and agree that their liability under this
Note shall not be affected by any renewal or extension in the time of payment hereof, or in any
indulgences, or by any release or change in any security for the payment of this Note, and hereby
consent to any and all renewals, extensions, indulgences, releases or changes.
THIS NOTE SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE WITH THE APPLICABLE LAWS OF THE
UNITED STATES OF AMERICA AND THE LAWS OF THE STATE OF TEXAS. BORROWER AGREES THAT THIS NOTE IS
PERFORMABLE IN TARRANT COUNTY, TEXAS AND THAT SUCH COUNTY IS PROPER VENUE FOR ANY ACTION OR
PROCEEDING INVOLVING THIS NOTE TO THE EXCLUSION OF ALL OTHER VENUES.
THIS INSTRUMENT SECURES A LINE OF CREDIT USED PRIMARILY FOR BUSINESS, COMMERCIAL OR
AGRICULTURAL PURPOSES.
THIS WRITTEN NOTE, THE CREDIT AGREEMENT AND THE OTHER LOAN DOCUMENTS REPRESENT THE FINAL
AGREEMENTS BETWEEN THE PARTIES AND MAY NOT BE CONTRADICTED BY EVIDENCE OF PRIOR, CONTEMPORANEOUS,
OR SUBSEQUENT ORAL AGREEMENTS OF THE PARTIES. THERE ARE NO UNWRITTEN ORAL AGREEMENTS BETWEEN THE
PARTIES.
2
EXECUTED as of the date and year first above written.
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BORROWER
:
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APPROACH RESOURCES I, LP,
a Texas limited partnership
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By:
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Approach Operating, LLC,
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a Delaware limited liability company,
its general partner
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By:
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Approach Resources Inc.,
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a Delaware corporation, its sole member
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By:
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J. Ross Craft, President
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3
EXHIBIT C
CERTIFICATE OF COMPLIANCE
The undersigned APPROACH RESOURCES I, LP, a Texas limited partnership (Borrowers), hereby
certifies that J. Ross Craft is authorized to execute this Certificate of Compliance (in the
capacity stated in his signature below). With reference to that certain Amended and Restated
Credit Agreement, dated as of February , 2007 (as same may be amended, modified, increased,
supplemented and/or restated from time to time, the Agreement) entered into between the Borrower
and THE FROST NATIONAL BANK as Agent and Lender, for itself and the Lenders signatory thereto
(the Lenders), the undersigned further certifies, represents and warrants on behalf of Borrower
that all of the following statements are true and correct (each capitalized term used herein having
the same meaning given to it in the Agreement unless otherwise specified):
(a) Borrower has fulfilled in all material respects its obligations under the Notes and
Loan Documents, including the Agreement, and all representations and warranties made herein
and therein continue (except to the extent they relate solely to an earlier date) to be true
and correct in all material respects.
(b) No Default or Event of Default has occurred under the Loan Documents, including the
Agreement.
(c) To the extent requested from time to time by the Agent, the certifying party shall
specifically affirm compliance of Borrower in all material respects with any of its
representations and warranties (except to the extent they relate solely to an earlier date)
or obligations under said instruments.
(d)
Financial Computations for the period ending _____.
(i) Current Ratio:
EXECUTED,
DELIVERED AND CERTIFIED TO this ___ day of ______, 200_.
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APPROACH RESOURCES I, LP,
a Texas limited partnership
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By:
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Approach Operating, LLC,
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a Delaware limited liability company,
its general partner
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By:
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Approach Resources Inc.,
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a Delaware corporation, its sole member
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By:
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J. Ross Craft, President
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1
EXHIBIT D
ASSIGNMENT AND ACCEPTANCE AGREEMENT
This Assignment Agreement (Assignment Agreement) between
(the Assignor) and
(the Assignee) is dated as of
, 2007. The parties hereto agree as follows:
1.
PRELIMINARY STATEMENT
. The Assignor is a party to a Credit Agreement (which, as it
may be amended, modified, renewed or extended from time to time is herein called the Credit
Agreement) described in Item 1 of Schedule 1 attached hereto (Schedule 1). Capitalized terms
used herein and not otherwise defined herein shall have the meanings attributed to them in the
Credit Agreement.
2.
ASSIGNMENT AND ASSUMPTION
. The Assignor hereby sells and assigns to the Assignee,
and the Assignee hereby purchases and assumes from the Assignor, an interest in and to the
Assignors rights and obligations under the Credit Agreement and the other Loan Documents, such
that after giving effect to such assignment the Assignee shall have purchased pursuant to this
Assignment Agreement the percentage interest specified in Item 3 of Schedule 1 of all outstanding
rights and obligations under the Credit Agreement and the other Loan Documents relating to the
facilities listed in Item 3 of Schedule 1. The aggregate Commitment (or Loans, if the applicable
Commitment has been terminated) purchased by the Assignee hereunder is set forth in Item 4 of
Schedule 1.
3.
EFFECTIVE DATE
. The effective date of this Assignment Agreement (the Effective
Date) shall be the later of the date specified in Item 5 of Schedule 1 or two Business Days (or
such shorter period agreed to by the Agent) after this Assignment Agreement, together with any
consents required under the Credit Agreement, are delivered to the Agent. In no event will the
Effective Date occur if the payments required to be made by the Assignee to the Assignor on the
Effective Date are not made on the proposed Effective Date.
4.
PAYMENT OBLIGATIONS
. In consideration for the sale and assignment of Loans
hereunder, the Assignee shall pay the Assignor, on the Effective Date, the amount agreed to by the
Assignor and the Assignee. On and after the Effective Date, the Assignee shall be entitled to
receive from the Agent all payments of principal, interest and fees with respect to the interest
assigned hereby. The Assignee will promptly remit to the Assignor any interest on Loans and fees
received from the Agent which relate to the portion of the Commitment or Loans assigned to the
Assignee hereunder for periods prior to the Effective Date and not previously paid by the Assignee
to the Assignor. In the event that either party hereto receives any payment to which the other
party hereto is entitled under this Assignment Agreement, then the party receiving such amount
shall promptly remit it to the other party hereto.
5.
RECORDATION FEE
. The Assignor and Assignee each agree to pay one-half of the
recordation fee required to be paid to the Agent in connection with this Assignment Agreement
unless otherwise specified in Item 6 of Schedule 1.
1
6.
REPRESENTATIONS OF THE ASSIGNOR; LIMITATIONS ON THE ASSIGNORS LIABILITY
. The
Assignor represents and warrants that (i) it is the legal and beneficial owner of the interest
being assigned by it hereunder, (ii) such interest is free and clear of any adverse claim created
by the Assignor and (iii) the execution and delivery of this Assignment Agreement by the Assignor
is duly authorized. It is understood and agreed that the assignment and assumption hereunder are
made without recourse to the Assignor and that the Assignor makes no other representation or
warranty of any kind to the Assignee. Neither the Assignor nor any of its officers, directors,
employees, agents or attorneys shall be responsible for (i) the due execution, legality, validity,
enforceability, genuineness, sufficiency or collectability of any Loan Document, including without
limitation, documents granting the Assignor and the other Lenders a security interest in assets of
the Borrower
[or Guarantor]
, (ii) any representation, warranty or statement made in or in
connection with any of the Loan Documents, (iii) the financial condition or creditworthiness of the
Borrower
[or Guarantor]
, (iv) the performance of or compliance with any of the terms or provisions
of any of the Loan Documents, (v) inspecting any of the property, books or records of the Borrower,
(vi) the validity, enforceability, perfection, priority, condition, value or sufficiency of any
collateral securing or purporting to secure the Loans or (vii) any mistake, error of judgment, or
action taken or omitted to be taken in connection with the Loans or the Loan Documents.
7.
REPRESENTATIONS AND UNDERTAKINGS OF THE ASSIGNEE
. The Assignee (i) confirms that
it has received a copy of the Credit Agreement and other Loan Documents, together with copies of
the financial statements requested by the Assignee and such other documents and information as it
has deemed appropriate to make its own credit analysis and decision to enter into this Assignment
Agreement, (ii) agrees that it will, independently and without reliance upon the Agent, the
Assignor or any other Lender and based on such documents and information as it shall deem
appropriate at the time, continue to make its own credit decisions in taking or not taking action
under the Loan Documents, (iii) appoints and authorizes the Agent to take such action as agent on
its behalf and to exercise such powers under the Loan Documents as are delegated to the Agent by
the terms thereof, together with such powers as are reasonably incidental thereto, (iv) confirms
that the execution and delivery of this Assignment Agreement by the Assignee is duly authorized,
(v) agrees that it will perform in accordance with its terms all of the obligations which by the
terms of the Loan Documents are required to be performed by it as a Lender, (vi) agrees that its
payment instructions and notice instructions are as set forth in the attachment to Schedule 1,
(vii) confirms that none of the funds, monies, assets or other consideration being used to make the
purchase and assumption hereunder are plan assets as defined under ERISA and that its rights,
benefits and interests in and under the Loan Documents will not be plan assets under ERISA,
(viii) agrees to indemnify and hold the Assignor harmless against all losses, costs and expenses
(including, without limitation, reasonable attorneys fees) and liabilities incurred by the
Assignor in connection with or arising in any manner from the Assignees non-performance of the
obligations assumed under this Assignment Agreement, and (ix) if applicable, attaches the forms
prescribed by the Internal Revenue Service of the United States certifying that the Assignee is
entitled to receive payments under the Loan Documents without deduction or withholding of any
United States federal income taxes.
8.
GOVERNING LAW
. This Assignment Agreement shall be governed by the internal law,
and not the law of conflicts, of the State of Texas
2
9.
NOTICES
. Notices shall be given under this Assignment Agreement in the manner set
forth in the Credit Agreement. For the purpose hereof, the addresses of the parties hereto (until
notice of a change is delivered) shall be the address set forth in the attachment to Schedule 1.
10.
COUNTERPARTS; DELIVERY BY FACSIMILE
. This Assignment Agreement may be executed in
counterparts. Transmission by facsimile of an executed counterpart of this Assignment Agreement
shall be deemed to constitute due and sufficient delivery of such counterpart and such facsimile
shall be deemed to be an original counterpart of this Assignment Agreement.
IN WITNESS WHEREOF, the duly authorized officers of the parties hereto have executed this
Assignment Agreement by executing Schedule 1 hereto as of the date first above written.
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[ASSIGNOR]
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By:
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Title:
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Address:
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[ASSIGNEE]
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By:
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Title:
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Address:
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3
(If required)
ACKNOWLEDGED AND CONSENTED TO:
THE FROST NATIONAL BANK,
as Agent
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By:
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John S. Warren, Senior Vice President
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APPROACH RESOURCES I, LP,
a Texas limited partnership
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By:
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Approach Operating, LLC,
a Delaware limited liability company,
its general partner
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By:
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Approach Resources Inc.,
a Delaware corporation, its sole member
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By:
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J. Ross Craft, President
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4
SCHEDULE 1
to Assignment Agreement
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1.
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Description and Date of Credit Agreement: $100,000,000 Amended and Restated Credit Agreement dated February ____,
2007
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2.
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Date of Assignment Agreement:
, 2007
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3.
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Amounts (As of Date of Item 2 above):
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Facility
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Facility
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Facility
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Facility
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1*
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2*
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3*
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4*
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a.
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Assignees percentage of each
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Facility purchased under the
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Assignment Agreement**
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%
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%
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%
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%
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b.
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Amount of each Facility purchased
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under the Assignment Agreement***
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$
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$
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$
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$
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4.
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Assignees Commitment (or Loans with
respect to terminated Commitments)
purchased hereunder:
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$
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5.
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Proposed Effective Date:
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6.
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Non-standard Recordation Fee Arrangement
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[Assignor/Assignee to pay 100% of fee]
[Fee waived by Agent]
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Accepted and Agreed:
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[NAME OF ASSIGNOR]
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[NAME OF ASSIGNEE]
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By:
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By:
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Title:
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Title:
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ACCEPTED
AND CONSENTED TO BY
APPROACH RESOURCES I, LP,
a Texas limited
partnership
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ACCEPTED
AND CONSENTED TO BY
THE FROST NATIONAL BANK
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By:
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By:
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Approach Operating, LLC,
a Delaware limited liability company,
its general partner
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John S. Warren, Senior Vice President
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By:
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Approach Resources, Inc.,
a Delaware corporation, its sole member
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By:
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J. Ross Craft, President
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5