8-K

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

FORM 8-K

 

 

CURRENT REPORT

Pursuant to Section 13 or 15(d) of

the Securities Exchange Act of 1934

Date of Report (Date of Earliest Event Reported) April 11, 2013

 

 

Matador Resources Company

(Exact name of registrant as specified in its charter)

 

 

 

Texas   001-35410   27-4662601

(State or other jurisdiction

of incorporation)

 

(Commission

File Number)

 

(IRS Employer

Identification No.)

5400 LBJ Freeway, Suite 1500, Dallas, Texas   75240
(Address of principal executive offices)   (Zip Code)

Registrant’s telephone number, including area code: (972) 371-5200

Not Applicable

(Former name or former address, if changed since last report)

 

 

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

 

¨ Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

 

¨ Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

 

¨ Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

 

¨ Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

 

 

 


Item 2.02 Results of Operations and Financial Condition.

Attached hereto as Exhibit 99.1 is a Press Release issued by Matador Resources Company (the “Company”) on April 15, 2013 regarding an update on various aspects of its business.

The Company expects to make presentations concerning its business to potential investors. The materials to be utilized during the presentations (the “Materials”) are furnished as Exhibit 99.2 hereto and incorporated herein by reference.

The information furnished pursuant to this Item 2.02, including Exhibits 99.1 and 99.2, shall not be deemed to be “filed” for the purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), and will not be incorporated by reference into any filing under the Securities Act of 1933, as amended (the “Securities Act”), unless specifically identified therein as being incorporated therein by reference.

In the Materials, the Company has included as “non-GAAP financial measures,” as defined in Item 10 of Regulation S-K of the Exchange Act, (i) earnings before interest expense, income taxes, depletion, depreciation and amortization, accretion of asset retirement obligations, property impairments, unrealized derivative gains and losses, certain other non-cash items and non-cash stock-based compensation expense, including stock option and grant expense and restricted stock and restricted stock units expense, and net gain or loss on asset sales and inventory impairment (“Adjusted EBITDA”) and (ii) present value discounted at 10% (pre-tax) of estimated total proved reserves (“PV-10”). In the Materials, the Company has provided reconciliations of the non-GAAP financial measures to the most directly comparable financial measures calculated and presented in accordance with generally-accepted accounting principles (“GAAP”) in the United States. In addition, in the Materials, the Company has provided the reasons why the Company believes those non-GAAP financial measures provide useful information to investors.

Item 5.02 Departure of Directors or Certain Officers; Election of Directors; Appointment of Certain Officers; Compensatory Arrangements of Certain Officers.

On April 11, 2013, the Board of Directors (the “Board”) of the Company appointed Carlos M. Sepulveda, Jr. to the Board. Mr. Sepulveda is retiring as President and CEO of Interstate Battery System International, Inc. — a position he has held since March 2004 — in May 2013 but will remain on that company’s board of directors. He serves as Chairman of the Board of Triumph Bancorp, Inc. and also serves on the Board of Directors and is Chair of the Audit Committee of Cinemark Holdings, Inc. The Company anticipates that Mr. Sepulveda will be appointed to the Audit Committee of the Board at the Board’s next regularly scheduled meeting in May 2013.

Mr. Sepulveda was appointed to serve as a Class I director and will stand for election as a Class I director at the 2013 Annual Meeting of Shareholders to serve for a term of office until the Company’s 2015 Annual Meeting of Shareholders and until the election and qualification of his successor or until his earlier death, retirement, resignation or removal.

Mr. Sepulveda will be compensated according to the director compensation program described in the Director Compensation section of the Company’s Proxy Statement for the Annual Meeting of Shareholders held on June 7, 2012 and incorporated herein by reference. He will also enter into an indemnification agreement with the Company in the form included as Exhibit 10.22 to Amendment No. 1 to the Registration Statement on Form S-1 filed on November 14, 2011 and incorporated herein by reference.

On February 7, 2012, upon the closing of our initial public offering, Mr. Sepulveda purchased $600,000 of the Company’s common stock in the directed share program from the underwriters in the offering at the initial price to the public.


Item 7.01 Regulation FD Disclosure.

Item 2.02 is incorporated herein by reference.

The information furnished pursuant to this Item 7.01, including Exhibits 99.1 and 99.2, shall not be deemed to be “filed” for the purposes of Section 18 of the Exchange Act and will not be incorporated by reference into any filing under the Securities Act unless specifically identified therein as being incorporated therein by reference.

Item 9.01 Financial Statements and Exhibits.

(d) Exhibits

 

Exhibit
No.

 

Description of Exhibit

99.1   Press Release, dated April 15, 2013.
99.2   Presentation Materials.


SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

 

  MATADOR RESOURCES COMPANY

Date: April 15, 2013

  By:  

/s/ David E. Lancaster

  Name:   David E. Lancaster
  Title:   Executive Vice President


Exhibit Index

 

Exhibit
No.

 

Description of Exhibit

99.1   Press Release, dated April 15, 2013.
99.2   Presentation Materials.
EX-99.1

Exhibit 99.1

 

LOGO

NEWS RELEASE

 

 

MATADOR RESOURCES COMPANY ANNOUNCES FIRST QUARTER 2013

PRODUCTION RESULTS AND ADDITION OF NEW DIRECTOR

DALLAS, Texas, April 15, 2013 – Matador Resources Company (NYSE:MTDR) (“Matador” or the “Company”), an independent energy company engaged in the exploration, development, production and acquisition of oil and natural gas resources, with a particular emphasis on oil and natural gas shale plays and other unconventional plays and currently focused on its Eagle Ford operations in South Texas, today provided this operational update and announced the appointment of a new member to its Board of Directors.

Matador announced first quarter 2013 oil and natural gas production of approximately 460,000 Bbl and 3.1 Bcf, respectively, compared to approximately 200,000 Bbl of oil and 3.2 Bcf of natural gas produced in the first quarter of 2012 and compared to guidance provided on Analyst Day on December 6, 2012 of approximately 360,000 Bbl of oil and 2.8 Bcf of natural gas. This increase was due primarily to the improved performance and productivity of its recent Eagle Ford wells as well as production increases resulting from the initiation of artificial lift operations on various producing wells. More specifically, Matador’s first quarter oil equivalent production was approximately 10,900 BOE per day, including approximately 5,100 Bbl of oil per day and 34.7 MMcf of natural gas per day, which was above the Company’s estimates of approximately 4,000 Bbl of oil per day and 31.1 MMcf of natural gas per day for the quarter as announced at Analyst Day on December 6, 2012. Matador’s first quarter oil production of 460,000 Bbl was a sequential increase of approximately 8% from 426,000 Bbl of oil produced in the fourth quarter of 2012. Notably, this increase has occurred despite the fact that about 10% of the Company’s Eagle Ford productive capacity was shut-in at various times during the quarter and that Matador has not added a new producing well since early February, due to its practice of pad drilling and simultaneous hydraulic fracturing operations.

Matador completed and began producing oil and natural gas from four operated Eagle Ford shale wells, all in LaSalle County, during January and early February 2013 and anticipates completing and initiating production from seven operated Eagle Ford shale wells during the second quarter, three in DeWitt County in late April and four in LaSalle County in late May. Beginning in late April, Matador plans to have one contracted drilling rig operating in LaSalle County in South Texas, while a second contracted drilling rig will initiate a three-well testing program of its acreage position in Southeast New Mexico and West Texas. The Company currently plans to resume its two-rig Eagle Ford drilling program in the third quarter of 2013.

The Company is also pleased to announce the addition of Mr. Carlos M. Sepulveda, Jr. to its Board of Directors. Carlos is currently the President and CEO of Interstate Battery System International, Inc., Chairman of the Board of Triumph Bancorp, Inc. and Director and Chairman of the Audit Committee of Cinemark Holdings, Inc. He will be retiring in May 2013 from Interstate Battery System International,


Inc., but will continue serving as a director of the company. Carlos holds a Bachelor of Business Administration degree, majoring in accounting and graduating with highest honors, from The University of Texas at Austin.

Joseph Wm. Foran, Matador’s Chairman, President and CEO commented, “We are very pleased by the strong production results achieved in early 2013 in our Eagle Ford program in South Texas and have been particularly encouraged by the performance of several of our recent wells, which reflects the continued improvements we are making in all aspects of our drilling, completion and production operations in South Texas. We are also looking forward to having Carlos, a long-time shareholder, on our Board with his experience not only in building a company but also his financial expertise and familiarity with the Company. We know that he will make immediate contributions in a number of areas.”

Forward-Looking Statements

This press release includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. “Forward-looking statements” are statements related to future, not past, events. Forward-looking statements are based on current expectations and include any statement that does not directly relate to a current or historical fact. In this context, forward-looking statements often address expected future business and financial performance, and often contain words such as “could,” “believe,” “would,” “anticipate,” “intend,” “estimate,” “expect,” “may,” “should,” “continue,” “plan,” “predict,” “potential,” “project” and similar expressions that are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Actual results and future events could differ materially from those anticipated in such statements, and such forward-looking statements may not prove to be accurate. These forward-looking statements involve certain risks and uncertainties, including, but not limited to, the following risks related to financial and operational performance: general economic conditions; our ability to execute our business plan, including whether our drilling program is successful; changes in oil, natural gas and natural gas liquids prices and the demand for oil, natural gas and natural gas liquids; our ability to replace reserves and efficiently develop current reserves; costs of operations; delays and other difficulties related to producing oil, natural gas and natural gas liquids; our ability to make acquisitions on economically acceptable terms; availability of sufficient capital to execute our business plan, including from future cash flows, increases in our borrowing base and otherwise; weather and environmental concerns; and other important factors which could cause actual results to differ materially from those anticipated or implied in the forward-looking statements. For further discussions of risks and uncertainties, you should refer to Matador’s SEC filings, including the “Risk Factors” section of Matador’s Annual Report on Form 10-K for the year ended December 31, 2012. Matador undertakes no obligation and does not intend to update these forward-looking statements to reflect events or circumstances occurring after the date of this press release, except as required by law, including the securities laws of the United States and the rules and regulations of the SEC. You are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date of this press release. All forward-looking statements are qualified in their entirety by this cautionary statement.


About Matador Resources Company

Matador is an independent energy company engaged in the exploration, development, production and acquisition of oil and natural gas resources in the United States, with a particular emphasis on oil and natural gas shale plays and other unconventional resource plays. Its current operations are focused primarily on the oil and liquids rich portion of the Eagle Ford shale play in South Texas and the Wolfcamp and Bone Spring plays in West Texas and Southeast New Mexico. Matador also operates in the Haynesville shale and Cotton Valley plays in Northwest Louisiana and East Texas.

For more information visit Matador Resources Company at www.matadorresources.com.

Contact Information

Mac Schmitz

Investor Relations

mschmitz@matadorresources.com

(972) 371-5225

EX-99.2
Investor Presentation
April 2013
Exhibit 99.2


2
Disclosure Statements
This presentation and statements made by representatives of Matador Resources Company (“Matador” or the
“Company”) during the course of this presentation include “forward-looking statements” within the meaning of Section 27A of the Securities Act of
1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. “Forward-looking statements” are statements related
to future, not past, events. Forward-looking statements are based on current expectations and include any statement that does not directly relate
to a current or historical fact.  In this context, forward-looking statements often address expected future business and financial performance, and
often contain words such as “could,” “believe,” “would,” “anticipate,” “intend,” “estimate,” “expect,” “may,” “should,” “continue,” “plan,” “predict,”
“potential,” “project” and similar expressions that are intended to identify forward-looking statements, although not all forward-looking statements
contain such identifying words. Actual results and future events could differ materially from those anticipated in such statements, and such
forward-looking statements may not prove to be accurate. These forward-looking statements involve certain risks and uncertainties, including, but
not limited to, the following risks related to our financial and operational performance: general economic conditions; our ability to execute our
business plan, including whether our drilling program is successful; changes in oil, natural gas and natural gas liquids prices and the demand for
oil, natural gas and natural gas liquids; our ability to replace reserves and efficiently develop our current reserves; our costs of operations, delays
and other difficulties related to producing oil, natural gas and natural gas liquids; our ability to make acquisitions on economically acceptable
terms; availability of sufficient capital to execute our business plan, including from our future cash flows, increases in our borrowing base  and
otherwise; weather and environmental conditions; and other important factors which could cause actual results to differ materially from those
anticipated or implied in the forward-looking statements. For further discussions of risks and uncertainties, you should refer to Matador’s SEC
filings, including the “Risk Factors” section of Matador’s most recent Annual Report on Form 10-K and any subsequent Quarterly Reports on Form
10-Q. Matador undertakes no obligation and does not intend to update these forward-looking statements to reflect events or circumstances
occurring after the date of this presentation, except as required by law, including the securities laws of the United States and the rules and
regulations of the SEC. You are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date of
this presentation.  All forward-looking statements are qualified in their entirety by this cautionary statement.
The Securities and Exchange Commission (SEC) permits oil and gas companies, in their filings with the SEC, to disclose only
proved, probable and possible reserves.  Potential resources are not proved, probable or possible reserves.  The SEC’s guidelines prohibit
Matador from including such information in filings with the SEC. 
Safe Harbor Statement –
Cautionary Note –


Company Summary


4
Company Overview
Completed IPO of 14,883,334 shares (12,209,167 primary) including overallotment at $12.00/share in March 2012
Exchange: Ticker
NYSE: MTDR
Shares Outstanding
(1)
55.84 million common shares
Share Price
(1)
$8.83/share
Market Capitalization
(1)
$493.1 million
2012 Actual                                2013 Guidance
Capital Spending
$335 million
$310 million
Total Oil Production
1.214 million barrels
1.6 to 1.8 million barrels
Total Natural Gas Production
12.5 billion cubic feet
11.0 to 12.0 billion cubic feet
Oil and Natural Gas Revenues
$156.0 million
$200
to
$220
million
(2)
Adjusted EBITDA
(3)
$115.9 million
$140
to
$160
million
(2)
(1)
As of April 11, 2013
(2)
Estimated 2013 oil and natural gas revenues and Adjusted EBITDA at midpoint of production guidance range using late November 2012 strip prices for oil and natural gas, plus property-specific differentials.  Estimated average realized prices for oil
and natural gas used in these estimates were $94.00/Bbl and $4.43/Mcf, respectively
(3)
Adjusted EBITDA is a non-GAAP financial measure. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to our net (loss) income and net cash provided by operating activities, see Appendix


Founded by Joe Foran in 1983
Foran Oil funded with $270,000 in contributed capital from 17 friends and family members
Foran Oil & Matador Petroleum
5
Matador History
Matador Resources Company
Founded by Joe Foran in 2003 with a proven management and technical team and board of directors
Grown through the drill bit, with focus on unconventional reservoir plays, initially in Haynesville
In 2008, sold Haynesville rights in approximately 9,000 net acres to Chesapeake for approximately
$180 million; retained 25% participation interest, carried working interest and overriding royalty interest
Relatively early in the play, redeployed capital into the Eagle Ford, acquiring over 30,000 net acres for
approximately $100 million, most in 2010 and 2011
Capital
spending
focused
on
developing
Eagle
Ford
and
transition
to
oil
IPO in February 2012 (NYSE: MTDR) had net cash proceeds of approximately $136.6 million
Predecessor Entities
(1)
Tom Brown purchased by Encana in 2004
Matador Today
Sold to Tom Brown, Inc.
(1)
in June 2003 for an enterprise value of $388 million in an all-cash transaction


6
Daily
Production
@
3/31/13
(1)
10,900 BOE/d
Oil Production (% total)
5,100 Bbl/d (47%)
Gas Production (% total)
34.7 MMcf/d (53%)
Proved Reserves @ 12/31/12
23.8 million BOE
% Proved Developed
58%
% Oil
44%
2013E CapEx
$310 million
% South Texas
~82%
% Oil and Liquids
~98%
2013E Anticipated Drilling
31.3 net wells
South Texas
27.4 net wells
West Texas / New Mexico
3.0 net wells
Gross
Acreage
(2)
156,846 acres
Net
Acreage
(2)
98,271 acres
Identified
Drilling
Locations
(3)(4)
873 gross / 413 net
(1)
Estimated average daily production for the three months ended March 31, 2013
(2)
At April 9, 2013
(3)
At December 31, 2012
(4)
Engineered Tier 1 and Tier 2 locations identified for potential future drilling, including specified production units and
estimated lateral lengths, costs and well spacing using objective criteria for designation.
Matador Resources Snapshot


7
Investment Highlights
Strong Financial Position and Prudent Risk Management
High Quality Asset Base in Attractive Areas
Eagle Ford provides immediate oil-weighted value and upside
Expanding acreage position in Delaware Basin in West Texas
Other key assets provide long-term option value on natural gas, with Haynesville, Bossier and Cotton
Valley assets all essentially held by production (HBP)
Proven Management and Technical Team and Active Board of Directors
Management averaging over 25 years of industry experience
Board with extensive industry experience and expertise as well as significant company ownership
Strong record of stewardship for nearly 30 years
Strong Growth Profile with Increasing Focus on Oil / Liquids
Oil production up almost five-fold in 2011 and up almost eight-fold in 2012
2013E capital expenditure program focused on oil and liquids exploration and development


Matador’s Continued Growth
8
(1)  Adjusted EBITDA is a non-GAAP financial measure. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to our net (loss) income andnet cash provided by operating activities, see Appendix
Note: 2013E at the mid-point of 2013 guidance, respectively
TOTAL OIL AND
TOTAL OIL PRODUCTION
NATURAL GAS REVENUES
ADJUSTED EBITDA
(1)


Growth in PV-10
(1)
from Proved Reserves
2008
(2)
2009
(2)
2010
(2)
2011
(2)
2012
(2)
(1)  PV-10 is a non-GAAP financial measure.  For a reconciliation of Standardized Measure (GAAP) to PV-10 (non-GAAP), see Appendix
(2)  At December 31 of each respective year
9
$41.00 oil
$5.71  gas
$57.65 oil
$3.87  gas
$75.96 oil
$4.38  gas
$92.71 oil
$4.12  gas
$91.21 oil
$2.76  gas
SEC Pricing
Oil, $/Bbl
Gas, $/MMBtu
$0
$50
$100
$150
$200
$250
$300
$350
$400
$450
$500


Eagle Ford
South Texas


Proved Reserves @ 12/31/12
14.3 million BOE
% Proved Developed
46%
% Oil / Liquids
72%
Daily Oil Production
(2)
5,050 Bbl/d
Gross Acres
(3)
41,279 acres
Net Acres
(3)
27,697 acres
Eagle Ford
(3)(4)
27,697 acres
Austin Chalk
(3)(4)
17,171 acres
2013E Anticipated Drilling
27.4 net wells
2013E CapEx Budget
$242.7 million
Identified Drilling Locations
(3)(5)
274 gross / 221 net
11
Eagle Ford and Austin Chalk Overview
Drilled and completed 38 gross / 36.5 net
operated
wells
to
date
(1)
Acreage positioned in some of the most
active counties for Eagle Ford and Austin
Chalk
Two rigs running, primarily focused on oil
and liquids
2013E capital expenditure program
focused on oil and liquids development
Proved reserves growth from 4.7 million
BOE at December 31, 2011 and less
than 0.1 million BOE at December 31,
2010
(1)
Total drilled and completed wells operated by Matador as of March 31, 2013
(2)
Estimated average daily oil production for the three months ended March 31, 2013 
(3)
At April 9, 2013
(4)
Some of the same leases cover the net acres shown for Eagle Ford and Austin Chalk. Therefore, the sum for both formations is not equal to 
the total net acreage
(5)
Engineered Tier 1 and Tier 2 locations identified for potential future drilling, including specified production units and estimated lateral lengths, costs and well
spacing using objective criteria for designation.


Value of Proved Reserves Up 70% and Shifting to Oil Over Past Year
Eagle Ford
$393.6 million, 93%
Haynesville
$21.8 million, 5%
Cotton Valley
$5.9 million, 1%
SE New Mexico
$2.0 million, 0%
December 31, 2012
PV-10
(1)
:
$423.2
million
(2)
(Standardized Measure = $394.6 million)
Proved Producing Reserves PV-10
(1)
: $297.5 million
Haynesville
$96.6 million, 39%
Cotton Valley
$19.5 million, 8%
Eagle Ford
$130.2 million, 52%
SE New Mexico
$2.4 million, 1%
December 31, 2011
PV-10
(1)
: $248.7 million
(Standardized Measure = $215.5 million)
Proved Producing Reserves PV-10
(1)
: $154.1 million
(1)
PV-10 is a non-GAAP financial measure. For a reconciliation of Standardized Measure (GAAP) to PV-10 (non-GAAP), see Appendix
(2)
Future undiscounted net revenue of $704.2 million using YE 2012 SEC pricing of $91.21/Bbl oil and $2.757/MMBtu gas
12


Highlights
13
Eagle Ford Properties are in Good Neighborhoods
Matador’s acreage in
counties with robust
transaction
activity
“good
neighborhoods”
Transaction values ranging
from $10,000 to $30,000 per
acre
Matador’s Eagle Ford
position approximately
28,000 net acres
Acreage in both the eastern
and western areas of the
play
Approximately 90% of
acreage in prospective oil
and liquids windows
Acreage offers potential for
Austin Chalk, Buda, Pearsall
and other formations
Good reputation with land and mineral owners
Note:  All Matador acreage at April 9, 2013 and all other acreage based on public information


Eagle Ford Properties
EAGLE FORD ACREAGE TOTALS
41,279 gross / 27,697 net acres
EAGLE FORD EAST
7,707 gross / 6,307 net acres
EOG OPERATED, MTDR WI ~21%
11,588 gross / 2,240 net acres
GLASSCOCK (WINN) RANCH
8,891 gross / 8,891 net acres
EAGLE FORD WEST
13,093 gross / 10,259 net acres
Matador Resources Acreage
San Antonio
Uvalde
Medina
Zavala
Frio
Dimmit
Webb
Bexar
Atascosa
McMullen
Live Oak
Bee
Goliad
Dewitt
Gonzales
Wilson
DRY GAS FAIRWAY
OIL FAIRWAY
Karnes
La Salle
COMBO LIQUIDS /
GAS FAIRWAY
14
Note:  All acreage at April 9, 2013


2012 Operated Eagle Ford Completion Results –
24 Hour IP Tests
15
Well Name
County
Completion Date
Perforated Length
(1)
Top Perf
(2)
Frac Stages
Oil IP
(3)(4)
Gas IP
(3)(4)
Oil Equiv IP
(5)
Choke
Pressure
Total  (ft.)
(ft.)
(Bbl/day)
(Mcf/day)
(BOE/day)
(inch)
(psi)
2012 Wells
Martin Ranch A 8H
La Salle
1/28/2012
6,092
9,559
21
1,089
831
1,228
26/64
1,750
Martin Ranch A 6H
La Salle
2/8/2012
6,509
9,550
22
689
1,714
975
26/64
1,650
Martin Ranch A 7H
La Salle
2/12/2012
4,902
9,502
17
609
481
689
26/64
1,040
Martin Ranch B 4H
La Salle
2/18/2012
3,801
9,701
13
595
968
756
26/64
1,320
Matador Sickenius Orca 1H
Karnes
3/16/2012
5,712
10,897
19
785
540
875
26/64
820
Northcut A 1H
La Salle
3/23/2012
4,446
9,209
15
583
592
682
26/64
1,000
Matador Danysh Orca 1H
Karnes
4/1/2012
4,962
11,537
17
1,012
1,126
1,200
26/64
1,175
Northcut A 2H
La Salle
5/1/2012
4,503
9,273
15
758
761
885
24/64
950
Matador Pawelek Orca 1H
Karnes
6/5/2012
6,103
11,231
20
670
739
793
16/64
2,510
Matador Pawelek Orca 2H
Karnes
6/7/2012
6,202
11,240
28
861
755
987
16/64
2,460
Matador Danysh Orca 2H
Karnes
6/10/2012
5,115
11,331
17
750
746
874
16/64
2,675
Glasscock Ranch 1H
Zavala
6/27/2012
5,352
7,166
18
307
0
307
pump
140
Matador K. Love Orca 1H
DeWitt
8/10/2012
5,077
13,048
17
1,793
2,171
2,155
16/64
5,280
Matador K. Love Orca 2H
DeWitt
8/11/2012
4,871
12,830
17
1,757
2,126
2,111
16/64
5,900
Northcut B 2H
LaSalle
9/6/2012
4,777
9,131
16
410
315
463
16/64
1,175
Northcut B 1H
LaSalle
9/12/2012
4,798
9,085
16
423
169
451
16/64
1,500
Matador Sickenius Orca 2H
Karnes
9/16/2012
5,982
10,829
25
851
556
944
16/64
2,000
Martin Ranch A 12H
LaSalle
10/4/2012
4,897
9,507
21
640
1,955
966
16/64
1,680
Matador K. Love Orca 4H
DeWitt
11/4/2012
4,012
12,611
14
1,509
841
1,649
16/64
4,900
Matador K. Love Orca 3H
DeWitt
11/6/2012
4,777
12,787
16
1,456
1,585
1,720
16/64
4,775
Martin Ranch B 13H
LaSalle
11/22/2012
5,364
9,476
23
519
162
546
14/64
2,125
Martin Ranch B 9RH
LaSalle
11/25/2012
5,364
9,428
23
482
240
522
14/64
2,000
Frances Lewton 2H
DeWitt
12/5/2012
6,277
13,072
21
1,178
4,203
1,879
14/64
6,150
Matador Cowey Orca 1H
DeWitt
12/9/2012
3,332
13,593
13
580
3,325
1,134
12/64
8,000
Northcut A 4H
LaSalle
12/18/2012
4,592
9,069
16
395
139
418
14/64
1,580
Average
5,113
18.4
828  Bbl/day
1,082  Mcf/day
1,008 BOE/day
1) Total length of perforated lateral from the first perforation to the last perforation
2) Top perf is measured depth
3) Rates as reported to the Texas Railroad Commission via W-2 or G-1 form
4) Rates are based on actual, stabilized, 24 hour production on a constant choke size
5) Oil equivalent rates are based on a 6:1 ratio of six Mcf gas per one Bbl oil


Eagle Ford Well Costs Declined During 2012 –
Western Acreage
16
$0
$2,000,000
$4,000,000
$6,000,000
$8,000,000
$10,000,000
$12,000,000
1
2
3
4
5
6
7
8
9
10
11
12
Total Cost
5000' Normalized Cost
Note: Wells are displayed in chronological order.  Wells drilled and completed using two casing strings.  Well drilling and completions costs only; costs do not include pipelines and lease facilities.


Eagle Ford Well Costs Declined During 2012 –
Eastern Acreage
17
$0
$2,000,000
$4,000,000
$6,000,000
$8,000,000
$10,000,000
$12,000,000
1
2
3
4
5
6
7
8
9
10
Total Cost
5000' Normalized Cost
Note: Wells are displayed in chronological order.  Wells drilled and completed using two casing strings.  Well drilling and completions costs only; costs do not include pipelines and lease facilities.


Average Frac Stage Cost per Well
18
$0
$50,000
$100,000
$150,000
$200,000
$250,000
$300,000
$350,000
$400,000
$450,000
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
     Bauxite               White Sand             Resin-Coated Sand
Note: Wells are displayed in chronological order; includes all Matador operated wells drilled and completed through December 31, 2012


Eagle Ford Well Estimated ROR as a Function of EUR and Well Cost
19
Note: Individual well economics only.  NGL price differential +$1.85/Mcf.  Oil price differential +$7.00/Bbl.
$90.00/Bbl NYMEX oil;
$3.00/Mcf NYMEX natural gas


20
Recent Technical Advancements in the Eagle Ford
Rotary Steerable Tools
Drilling time in curve and lateral reduced by two days
Measurement While Drilling (MWD) telemetry closer to drill bit
Improves ability to stay in “sweet-spot”
Removes sumps and high-angle curves
Improved frac design
Increases Stimulated Rock Volume (SRV)
Tighter fracture spacing (25% more fractures than previous design)
35 Bbl/ft Frac fluid (75% increase from previous design)
Zipper Fracs (simultaneous frac operations)
Daily fixed cost reduced by 20%
Increases drainage efficiency
Choke size reduction
Delays effects of pressure-dependent formation permeability
Increases Estimated Ultimate Recovery (EUR)
Delays installation of artificial lift
Lowers bottom-hole pressure differential
Mitigates damage to proppant pack
Artificial lift
Pumping units with pump-off controllers on low gas/oil ratio (GOR) wells
Gas-lift valves on high gas/oil ratio (GOR) wells
Electric Submersible Pumps (ESP) to accelerate unloading frac fluids


Drilling Times and Efficiencies
21
Note: As of January 25, 2013
* Bold wells utilized rotary steerable systems
First 4 Wells
Recent Wells


22
San Antonio
Multi-Pay Fairway
with Pearsall, Austin Chalk and Buda potential
OIL FAIRWAY
OIL FAIRWAY
DRY GAS FAIRWAY
DRY GAS FAIRWAY
Emerging Multi-Pay Area in Eagle Ford Oil Fairway and MTDR Acreage
Note:  All acreage at April 9, 2013
Medina
Zavala
Frio
Dimmit
La Salle
Webb
Bexar
Atascosa
McMullen
Dewitt
Gonzales
Wilson
Karnes
Live Oak
Bee
Goliad
Guadalupe
Uvalde
Matador Resources Acreage


Delaware Basin
Southeast New Mexico and West Texas


24
Gross
Acres
(1)
25,477 acres
Net
Acres
(1)
15,117 acres
Southeast New Mexico / West Texas
Foothold of existing production and
reserves
Acreage position in good neighborhoods,
surrounded
by
other
operators’
ongoing
drilling
In March and April 2013, acquired
approximately 9,617 gross and 7,446 net
acres in Lea and Eddy Counties, New
Mexico for approximately $11.3 million
Company considers 17,795 gross and
13,049 net acres to be prospective for the
Wolfcamp, Bone Spring and other oil and
liquids-rich targets
(1)
Acreage at April 9, 2013
RANGER-
QUERECHO
WOLF
INDIAN
DRAW
LOVING


25
Wolfbone Play in the Delaware Basin (West Texas) Stratigraphic Column
Avalon Shale
Depth: 7,900’
8,300’
(Oil Window)
Density Porosity: 12-14%
Thickness: 300-500 ft.
Normal Pressure (0.45 psi/ft.)
Total Organic Carbon (TOC) 5-8%
XRD: 15-20% clay and 40-60% silica
IP: 100-270 Bbl/d   200-1,200 Mcf/d
Middle Wolfcamp
Depth: 11,500’
12,000’
Density Porosity: 12-15%
Thickness: 200-300 ft.
Geopressure (0.7psi/ft.)
Total Organic Carbon (TOC) 2-4%
Upper Wolfcamp
Depth: 10,500’
10,600’
(Oil Window)
Density Porosity: >10%
Thickness: 280-350 ft.
Geopressure (0.7psi/ft.)
IP: 121-900 Bbl/d   250-3,300 Mcf/d
Horizontal Targets
1
st
2
nd
3
rd
Bone Spring
Depth: 8,500’
10,600’
(Oil Window)
Density Porosity: >10%
Thickness: 10-100 ft.
Normal Pressure (0.45 psi/ft.)
IP: 10-600 Bbl/d   500-2,500 Mcf/d
Note:  Information from public sources


Ranger Prospect Area: Proposed Wolfbone
Multi-Zone Exploration Program and Surrounding Results
Concho
Stratojet 31 State #1H
2
Bone
Spring
18 mo.cum:
316 MBO; 378 MMcf
Cimarex Energy
Lynch 23 Fed #1H
3
Bone
Spring
13 mo.cum:
142 MBO; 99 MMcf
Legacy Operating
Lee Unit 4H
3
Bone
Spring
16 mo.cum:
63 MBO; 55 MMcf
Concho
AirCobra 12 #2H
3
Bone
Spring
17 mo.cum:
246 MBO; 132 MMcf
XOG Operating
(Vertical well)
Jordan B #1
Wolfcamp
20 years cum:
386 MBO; 5 Bcf
Concho
(Vertical well)
Neuhaus 14 Fed #2
Wolfcamp
8 years cum:
156 MBO; 2 Bcf
26
Proposed location for
Matador 2013 test well
3 Rivers Oper
Eagle 2 State 6H
3
Bone Spring
2 mo.cum:
32 MBO; 13 MMcf
Cimarex Energy
Mallon 35 Fed 4H
3
Bone
Spring
19 mo.cum:
33 MBO; 20 MMcf
Amtex Energy
Teapot 2H
2
Bone Spring
1 mo.cum:
52 MBO; 37 MMcf
Concho
Condor State #1H
2
Bone
Spring
IP (Oct 2012)
339 BOPD
Concho
Haumea St. #2H
2
Bone
Spring
Completed March 2013
Now Flowing Back
nd
rd
rd
rd
nd
nd
nd
rd
rd
Note: All acreage at April 9, 2013.  Well information from public sources.


Wolf Leasehold:  Proposed Wolfbone
Multi-Zone Exploration Program and Surrounding Results
Wolf Energy
Wolf #1
(Vertical well)
3
BS / Upr Wolfcamp
33 years cum:
58 MBO; 620 MMcf
Wolf Energy
Dorothy White #1
(Vertical well)
3
BS / Upr Wolfcamp
17 years  cum:
25 MBO; 92 MMcf
Chesapeake
Johnson 1-88 Lov #1H
Wolfcamp
10 mo.cum:
72 MBO; 295 MMcf
Chesapeake
Johnson 1-86 (1H)
Wolfcamp
17 mo.cum:
122 MBO; 344 MMcf
Chesapeake
Johnson 1-76 (1H)
Wolfcamp
22 mo.cum:
140 MBO; 475 MMcf
Energen
Grayling 1-69
IP: 791 BOPD 7.3 MMcf/d
3,500 psi FTP
4 mo.cum: 40 MBO; 370 MMcf on
restricted choke
Energen
Black Mamba 1-57
Wolfcamp
3 mo.cum:
61 MBO; 180 MMcf
Proposed location for
Matador 2013 test well
27
Note: All acreage at April 9, 2013.  Well information from public sources.
Chesapeake
Johnson 1-75 Lov #1H
Wolfcamp
6 mo.cum:
51 MBO; 120 MMcf
Energen
Bushmaster 1-58
Wolfcamp
4 mo.cum:
27 MBO; 100 MMcf
Energen
Katie 1-72
Wolfcamp
5 mo.cum:
40 MBO; 120 MMcf
OXY
Reagan-McElvain #1H
Spud 6/27/2012
IP: 570 BOPD 2.6 MMcf/d
2 mo.cum:
37 MBO; 92 MMcf
rd
rd


Haynesville & Cotton Valley
Northwest Louisiana and East Texas


Tier 1 Haynesville and Elm Grove Cotton Valley Acreage Positions
Almost all prospective Haynesville acreage is HBP
Note: All acreage at April 9, 2013
CADDO
BOSSIER
BIENVILLE
RED RIVER
Elm Grove Cotton Valley:
49 Net Locations
Matador Operated
Acreage: 9,980 gross, 9,800 net
Locations: 71 gross, 49 net (@ 3-4
locations/section)
Potential Resource
(1)
: 135 –
170 Bcf net
Tier 1 Haynesville:
50 Net Locations
Acreage: 12,568 gross, 5,737 net
Locations: 397 gross, 50 net (@ 7
locations/section)
Potential Resource
(1)
: 250 –
310 Bcf net
MTDR CV Horizontal
T. Walker #1H
MTDR Haynesville
Williams (BLM) #1H
TIER 1:
6 –
10+ Bcf
TIER 2:
4 –
6 Bcf
TIER 3:
2 –
4 Bcf
29
Note: Matador does not include any of this potential resource inits proved natural gas reserves at December 31, 2012
MTDR Haynesville
L.A. Wildlife #1H
(1) Potential resource should not be considered  proved  natural gas reserves.  Potential resource may be converted to proved  natural gas reserves as a result of successful drilling operations and higher natural gas prices


30
Haynesville Well Economics –
Tier 1 Area
Note: Individual well economics only.  D&C cost = drilling and completion cost.  Natural gas price differential = ($0.85)/Mcf.
Natural Gas Price, $/Mcf


31
Cotton Valley Horizontal Well Economics
Note: Individual well economics only.  D&C cost = drilling and completion cost.  Natural gas price differential = (10%)
Natural Gas Price, $/Mcf


Gracie
Wyoming, Utah and Idaho


Matador Gracie Project Total Prospect Acreage
IDAHO
UTAH
WYOMING
61,897 gross acres
30,492 net acres
Crawford Federal  #1H
33
Note: All acreage at April 9, 2013
Crawford Federal #1H
completion scheduled
for summer 2013


Southwest Wyoming Stratigraphy and Target Zones
Lamberson, Paul, 1982, The Fossil Basin
and its Relationship to the
Absaroka Thrust System,
Wyoming and Utah, RMAG
13% TOC
Meade Peak Shale
Cretaceous Shales
2% TOC
Crawford Federal #1:
Drilled straight hole in late 2011
Encountered 161’
Meade Peak with 46’
of main pay
Recovered 50’
conventional core
across pay zone
TOC
ave
4.52%  (Maximum 14.2%)
Thermally mature: Ro 1.69%
Porosity Average: 3.0–
5.0%
Micro-Darcy Permeability
Drilled 2,500-ft horizontal lateral in late
2012; plan to complete in summer 2013
34


2013 Capital Investment Plan


2013 Capital Investment Plan Highlights
36
2013 projected capital expenditures of approximately $310 million
Drill and complete or participate in 48 gross/31.3 net wells in 2013
Including
31.0
gross/25.8
net
Eagle
Ford
Shale
and
3.0
gross/3.0
net
Bone
Spring/Wolfcamp
Also includes 3.0 gross/1.6 net exploratory Austin Chalk, Buda and Edwards tests
Includes approximately $25 million for pipelines/facilities and $25 million for land/seismic acquisition
Compares to 2012 Drilling Program of 28 gross / 24.5 net wells for $334.6 million in capital expenditures
2013 expenditures are estimated to be funded 50% through cash flows and 50% through borrowings
under revolving credit facility
2013 Production Expectations
Oil
production
of
1.6
to
1.8
million
barrels
mid-point
up
40%
from
1.2
million
barrels
in
2012
Natural
gas
production
of
11.0
to
12.0
Bcf
mid-point
down
8%
from
12.5
Bcf
in
2012
2013 Financial Expectations
Oil
and
natural
gas
revenues
(1)
of
$200
to
$220
million
mid-point
up
35%
from
$156.0
million
in
2012
Adjusted
EBITDA
(1)(2)
of
$140
to
$160
million
mid-point
up
29%
from
$115.9
million
in
2012
Total borrowings outstanding estimated to be $310 to $320 million at YE 2013
Maintain financial discipline by funding 2013 capital expenditures through operating cash flows
and borrowings under revolving credit facility
2013 oil production volumes well hedged to protect cash flows below about $88/Bbl oil price
Current borrowings are about 1.5x estimated 2013 operational cash flows
(1)  Estimated 2013 oil and natural gas revenues and Adjusted EBITDA at midpoint of production guidance range using late November 2012 strip prices for oil and natural gas, plus property-specific differentials.  Estimated average realized prices for
oil and natural gas used in these estimates were $94.00/Bbl and $4.43/Mcf, respectively
(2)  Adjusted EBITDA is a non-GAAP financial measure. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to our net (loss) income andnet cash provided by operating activities, see Appendix


37
2013 Oil Production
Estimated total oil production of 1.6 to
1.8 million barrels
Mid-point is an increase of 40% from
2012
Oil production expected to decline from
year-end 2012 levels in early 2013
Production delays, shut-ins due to pad drilling,
zipper fracs, etc.
Q1 2013 production of approx. 5,100
Bbl/d exceeded guidance estimates of
approx. 4,000 Bbl/d
2013 Natural Gas Production
Estimated total natural gas production of
11.0 to 12.0 Bcf
Mid-point is a decrease of 8% from 2012
Gas production expected to remain
relatively flat during 2013, but should
include higher percentage of liquids-rich
gas
2013 Production Expectations
Oil
Production
(1)
(Bbl/d)
Natural
Gas
Production
(1)
(MMcf/d)
0
1,000
2,000
3,000
4,000
5,000
6,000
1Q13
2Q13
3Q13
4Q13
0.0
10.0
20.0
30.0
40.0
1Q13
2Q13
3Q13
4Q13
First Quarter 2013
First Quarter 2013
(1) Estimated (as of December 6, 2012) quarterly average oil and natural gas production at midpoint of guidance range


Funding for 2013 Capital Investment Plan
38
Maintain financial discipline by anticipated funding of 2013 capital expenditures through
operating cash flows and borrowings under revolving credit facility
Most of 2013 Eagle Ford program is development drilling and largely de-risked by 2012 results
As of April 9, 2013, 1.2 million barrels of 2013 oil production hedged protecting cash flows below
approximately $88/Bbl oil price
Credit facility status at April 9, 2013
Borrowing base of $255 million; total facility size of $500 million; facility matures in December 2016
Borrowings outstanding of $215 million
Ability to request quarterly borrowing base increases with growth in oil and natural gas
reserves throughout 2013
Estimated borrowings outstanding of $310 to $320 million at YE 2013
Additional flexibility to manage liquidity
No long-term drilling rig or service contract commitments
$25 million estimated for discretionary land/seismic acquisitions
No significant non-operated well obligations
Simple capital structure; no high-yield debt or convertibles on balance sheet


39
Continued Oil/Liquids Focus to Fuel 2013 Growth
2013 Anticipated Drilling
2013E CapEx
Gross Wells
Net Wells
(in millions)
Total
Total
%
Total
%
South Texas
Eagle Ford Shale
31.0
            
25.8
            
82.4%
 
$217.0
70.1%
  
Austin Chalk, Buda, Edwards
3.0
              
1.6
              
5.1%
   
$5.9
1.9%
    
Facilities/Pipelines/Etc.
-
                   
-
                   
-
         
$19.8
6.4%
    
Area Total
34.0
            
27.4
            
87.5%
 
$242.7
78.4%
  
West Texas/Southeast New Mexico
Bone Spring/Wolfcamp
3.0
              
3.0
              
9.6%
   
$30.2
9.8%
    
Facilities/Pipelines/Etc.
-
                   
-
                   
-
         
$5.4
1.7%
    
Area Total
3.0
              
3.0
              
9.6%
   
$35.6
11.5%
  
Northwest Louisiana
Haynesville Shale
10.0
            
0.5
              
1.6%
   
$5.1
1.7%
    
Southwest Wyoming
Meade Peak Shale
1.0
              
0.4
              
1.3%
   
$1.0
0.3%
    
Other
Land/Seismic/Etc.
-
                   
-
                   
-
         
$25.0
8.1%
    
Total
48.0
            
31.3
            
100.0%
$309.4
100.0%
 


40
EAGLE FORD EAST
7,707 gross / 6,307 net acres
EOG OPERATED, MTDR WI ~21%
11,588 gross / 2,240 net acres
GLASSCOCK (WINN) RANCH
8,891 gross / 8,891 net acres
EAGLE FORD WEST
13,093 gross / 10,259 net acres
San Antonio
Zavala
Frio
Dimmit
La
Salle
Webb
Bexar
Atascosa
McMullen
Dewitt
Gonzales
Wilson
COMBO LIQUIDS /
GAS FAIRWAY
DRY GAS FAIRWAY
OIL FAIRWAY
Glasscock
Ranch
Shelton
Newman
ZLS
Martin
Ranch
Northcut
Affleck
Troutt
Sutton
MRC/EOG
Pawelek
Danysh
Sickenius
Lyssy
Repka
RCT Wilson
Love
Cowey
Keseling
Finney
Lewton
Hennig
Nickel
Ranch
Pena
Matador Resources Acreage
Karnes
13
2
2
1
3
4 (Non-Op)
4
1 (Buda –
Non-Op)
1 (Edwards –
Non-Op)
1
1
1 (Austin Chalk)
2013 South Texas Drilling Plan
EAGLE FORD ACREAGE TOTALS
41,279 gross / 27,697 net acres
Potential Remaining Eagle Ford Drilling Locations*
274 gross/221 net locations
Tier 1 –
155 gross/125 net locations (40 to 80-acre spacing)
Tier 2 –
119 gross/96 net locations (primarily Glasscock Ranch and
Sutton, both HBP, 80 to 120-acre spacing)
No Eagle Ford locations estimated for Atascosa acreage
Numbers do not include any potential locations for other horizons –
e.g., Austin Chalk, “Chalkleford”, Buda, Pearsall
*At December 31, 2012
(1)  We define Tier 1 Eagle Ford locations as those locations that we anticipate to have estimated ultimate recoveries of 225,000 Bbl of oil or greater.
(2)  We define Tier 2 Eagle Ford locations as those locations that we anticipate to have estimated ultimate recoveries of between 150,000 Bbl and 225,000 Bbl of oil or locations that are primarily prospective for natural gas.
Note:  All acreage values at April 9, 2013.  Net wells reflect Matador’s working interest ownership.
# -
Gross wells planned in 2013;  All Matador
operated Eagle Ford wells unless noted
otherwise
34 gross/27.4 net wells planned in 2013
dina


Matador’s acreage position at April 9, 2013 shown in red.  Note:  Certain additional Matador acreage in Southeast
New Mexico/West Texas not considered prospective as of December 31, 2012.
41
Southeast NM / West Texas Acreage and 2013 Drilling Plan
RANGER
LOVING
WOLF
SOUTHEAST NM / WEST TEXAS
PROSPECTIVE ACREAGE
17,795 gross / 13,049 net acres
RANGER
4,308 gross / 2,727 net acres
Ranger A2
Primary Target: 2nd Bone Spring Sand
Ranger A1
Primary Targets: Wolfcamp/Bone Spring
WOLF
5,203 gross / 3,057 net acres
# -
Matador operated wells planned in 2013
3 gross/3 net horizontal wells planned in 2013
Wolf 1
Primary Target: Wolfcamp Shale


Recent Production and Operational Updates
42
First Quarter 2013 Production
Q1 2013 oil and natural gas production of approximately 460,000 Bbl and 3.1 Bcf, respectively,
compared to approximately 200,000 Bbl of oil and 3.2 Bcf of natural gas produced in Q1 2012
Q1 2013 production was approximately 10,900 BOE per day, including approximately 5,100 Bbl of oil
per day and 34.7 MMcf of natural gas per day
-
Above the Company’s estimates of approximately 4,000 Bbl of oil per day and 31.1 MMcf of
natural gas per day for the quarter as announced at Analyst Day on December 6, 2012
Increase occurred despite about 10% of the Company’s Eagle Ford productive capacity being shut-in
and no additional producing wells being added since early February, due to pad drilling and
simultaneous hydraulic fracturing operations
March and April 2013 Acreage Acquisitions
Acquired approximately 9,617 gross and 7,446 net acres in Lea and Eddy Counties, New Mexico for
approximately $11.3 million
Approximately
17,795
gross
and
13,049
net
acres
of
Southeast
New
Mexico
and
West
Texas
acreage
considered
prospective
for
the
Wolfcamp,
Bone
Spring
and
other
oil
and
liquids-rich
targets
Expect to begin testing acreage beginning in late April 2013
Filed Universal Shelf Registration Statement on Form S-3
Under the registration statement, when declared effective by the SEC, the Company may offer to the public
from time to time in one or more offerings up to $300 million of its senior and subordinated debt securities,
common stock, preferred stock, warrants or any combination of the foregoing at prices and on terms that
Matador will decide at the time of any offering


43
2013
Revenue
and
Adjusted
EBITDA
(1)(2)
Estimated oil and natural gas revenues of $200 to
$220 million
Mid-point is an increase of 35% from $156.0
million in 2012
Estimated Adjusted EBITDA
(1)(2)
of $140 to $160
million
Mid-point is an increase of 29% from $115.9
million in 2012
Adjusted EBITDA
(1)(2)
growth expected to be
impacted by lower oil price realizations and an
estimated decrease of approximately $13 million in
realized hedging gains compared to 2012
2013
Operating
Costs
Estimated average unit costs per BOE
Production taxes/marketing = $4.10
Lease operating = $8.20
G&A = $4.70
Operating cash costs, excluding interest = $17.00
DD&A = $29.50
2013 Financial Expectations
Oil
and
Natural
Gas
Revenues
(2)
(millions)
Adjusted
EBITDA
(1)(2)
(millions)
(1)  Adjusted EBITDA is a non-GAAP financial measure. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to our net (loss) income and net cash provided by operating activities, see Appendix
(2)  Estimated 2013 oil and natural gas revenues and Adjusted EBITDA at midpoint of production guidance range using late November 2012 strip prices for oil and natural gas, plus property-specific differentials.  Estimated average realized prices 
      for oil and natural gas used in these estimates were $94.00/Bbl and $4.43/Mcf, respectively


Appendix


Board
of
Directors
and
Special
Board
Advisors
Expertise
and
Stewardship
45
Board Members
and Advisors
Professional Experience
Business Expertise
Dr. Stephen A. Holditch
Director
-
Professor Emeritus and Former Head of Dept. of Petroleum Engineering, Texas A&M University
-
Founder and Former President S.A. Holditch & Associates
-
Past President of Society of Petroleum Engineers
Oil & Gas Operations
David M. Laney
Lead Director
-
Past Chairman, Amtrak Board of Directors
-
Former Partner, Jackson Walker LLP
Law & Investments
Gregory E. Mitchell
Director
-
President and CEO, Toot’n Totum Food Stores
Petroleum Retailing
Dr. Steven W. Ohnimus
Director
-
Retired VP and General Manager, Unocal Indonesia
Oil & Gas Operations
Michael C. Ryan
Director
-
Partner, Berens Capital Management
International Business and
Finance
Margaret B. Shannon
Director
-
Retired VP and General Counsel, BJ Services Co.
-
Former Partner, Andrews Kurth LLP
Law and
Corporate Governance
Carlos M. Sepulveda, Jr.
Director
-
President
and
CEO,
Interstate
Battery
System
International,
Inc.
(retiring
May
2013)
-
Chairman of the Board, Triumph Bancorp, Inc.
-
Director and Audit Chair, Cinemark Holdings, Inc.
Business and Finance
Marlan W. Downey
Special Board Advisor
-
Retired President, ARCO International
-
Former President, Shell Pecten International
-
Past President of American Association of Petroleum Geologists
Oil & Gas Exploration
Wade I. Massad
Special Board Advisor
-
Managing Member, Cleveland Capital Management, LLC
-
Former EVP Capital Markets, Matador Resources Company
-
Formerly with KeyBanc Capital Markets and RBC Capital Markets
Capital Markets
Edward R. Scott, Jr.
Special Board Advisor
-
Former Chairman, Amarillo Economic Development Corporation
-
Law Firm of Gibson, Ochsner & Adkins
Law, Accounting and Real
Estate Development
W.J. “Jack”
Sleeper, Jr.
Special Board Advisor
-
Retired
President,
DeGolyer
and
MacNaughton
(Worldwide
Petroleum
Consultants)
Oil & Gas Executive
Management


Proven Management Team –
Experienced Leadership
46
Management Team
Background and Prior Affiliations
Industry
Experience
Matador
Experience
Joseph Wm. Foran
Founder, Chairman and CEO
-
Matador Petroleum Corporation, Foran Oil Company,
J Cleo Thompson Jr. and Thompson Petroleum Corp.
32 years
Since Inception
David E. Lancaster
EVP and COO
-
Schlumberger, S.A. Holditch & Associates, Inc., Diamond
Shamrock
33 years
Since 2003
Matthew V. Hairford
EVP and Head of Operations
-
Samson, Sonat, Conoco
28 years
Since 2004
David F. Nicklin
Executive Director of Exploration
-
ARCO, Senior Geological Assignments in UK, Angola,
Norway and the Middle East
41 years
Since 2007
Bradley M. Robinson
VP, Reservoir Engineering
-
Schlumberger, S.A. Holditch & Associates, Inc.,
Marathon
35 years
Since Inception
Craig N. Adams
VP and General Counsel
-
Baker Botts L.L.P., Thompson & Knight LLP
20 years
Since 2012
Ryan C. London
VP and General Manager
-
Matador Resources Company
9 years
Since 2003
Kathryn L. Wayne
Controller and Treasurer
-
Matador Petroleum Corporation, Mobil
28 years
Since Inception


47
2013 and 2014 Hedging Profile
1.20 million barrels of oil hedged for
remainder of 2013 at weighted average
floor and ceiling of $88/Bbl and $107/Bbl,
respectively
6.6 Bcf of natural gas hedged for
remainder of 2013 at weighted average
floor and ceiling of $3.27/MMBtu and
$4.55/MMBtu, respectively
7.6 million gallons of natural gas liquids
hedged for remainder of 2013 at weighted
average price of $1.21/gal
1.68 million barrels of oil, 8.4 Bcf of natural
gas and 3.7 million gallons of natural gas
liquids hedged for 2014
Note: Hedged volumes shown in table for 2013 are for remainder of 2013; volumes shown in table for 2014 are for full calendar year.
At April 9, 2013, Matador has:
Oil Hedges (Costless Collars)
2013
2014
Total Volume Hedged by Ceiling (Bbl)
1,020,000
1,680,000
Weighted Average Price ($ / Bbl)
$109.39
$98.55
Total Volume Hedged by Floor (Bbl)
1,020,000
1,680,000
Weighted Average Price ($ / Bbl)
$87.35
$87.79
Oil Hedges (Swaps)
2013
2014
Total Volume Hedged (Bbl)
180,000
-
Weighted Average Price ($ / Bbl)
$90.43
-
Natural Gas Hedges (Costless Collars)
2013
2014
Total Volume Hedged by Ceiling (Bcf)
6.55
8.40
Weighted Average Price ($ / MMBtu)
$4.55
$5.15
Total Volume Hedged by Floor (Bcf)
6.55
8.40
Weighted Average Price ($ / MMBtu)
$3.27
$3.32
Natural Gas Liquids (NGLs) Hedges (Swaps)
2013
2014
Total Volume Hedged (gal)
7,581,600
3,708,000
Weighted Average Price ($ / gal)
$1.21
$1.44


Reserves Summary at December 31, 2012
48
Total proved reserves: 23.8 million BOE at December 31, 2012, including 10.5 million Bbl of oil and 80.0 Bcf
of natural gas
Oil reserves grew 176% to 10.5 million Bbl from 3.8 million Bbl at December 31, 2011
PV-10
(1)
increased
70%
to
$423.2
million
from
$248.7
million
at
December
31,
2011,
despite
removal
of
close to 100 Bcf of proved undeveloped Haynesville shale gas reserves at June 30, 2012
Oil
reserves
comprised
44%
(1
Bbl
=
6
Mcf
basis)
of
total
proved
reserves
at
December
31,
2012,
up
from
12% at December 31, 2011
Eagle
Ford
reserves
comprised
93%
of
total
PV-10
(1)
at
December
31,
2012
as
compared
to
52%
at
Sequential growth from September 30, 2012 to December 31, 2012
Oil reserves grew 25% to 10.5 million Bbl from 8.4 million Bbl at September 30, 2012
PV-10
(1)
increased 16% to $423.2 million from $363.6 million at September 30, 2012
(1) PV-10 is a non-GAAP financial measure.  For a reconciliation of Standardized Measure (GAAP) to PV-10 (non-GAAP), see Appendix
December 31, 2011


49
Financial Performance
Oil and Natural Gas Revenues
($ in mm)
Total Realized Revenues
(2)
($ in mm)
Adjusted EBITDA
(1)
($ in mm)
Average Daily Production
(BOE/d)
(1) Adjusted EBITDA is a non-GAAP financial measure. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to our net (loss) income and net cash provided by operating activities, see Appendix
(2)  Includes realized gain on derivatives


South Texas: Pearsall Play
Anadarko
Newfield
Chesapeake
Shell
Gas Activity
Top Pearsall Depth Map
CI = 500’
Cheyenne
Chilipitin LTD #101H Permit
Note: All acreage at April 9, 2013.  Well data from public information.
CHK –
Wilson C #1H
3.2 MMcf/d, 334 Bbl/d
97 Bbls/MMcf
Abnd. For EGFD
Cabot/Osaka JV
Osaka 35% ($14,285/ac. –
17,500ac.)
6 Horiz. Drilled
3 Permits
Schorp-White Ranch #101H
full mo. –
4,535 Bbl, 43MMcf
RH Pickens #101H
1
full mo. –
5,339 Bbl, 16MMcf
EOG Tests
500 –
2000 Bbl/mo.
Temp. Abnd.  or EGFD Horiz.
CHK
Ralph Edwards E #1H
IP: 135 Bbl/d, 1752 Mcf/d
17/64”
w/ 2797 Ftp
5 mo.cum 6,917 Bbl, 153 MMcf
EOG
Robert Hindes #1H
IP: 263 Bbl/d, 4.3 MMCF/d
26/64”
w/ 1977 Ftp
Cheyenne
Indio Tanks Horiz. program
4 horizs w/ 700 to 450 Bbl/d
Plus 4 to 6 MMcf/d
Yields 83 to 63 Bbls/MMcf
Cromwell #1H –
5 mo. 4 MBbl, 71 MMcf
A Williams B #1H –
5 mo. 20 MBbl, 129 MMcf
ZCW #1H –
5 mo. –
17 MBbl, 154 Mcf
Rosetta
Tom Hanks #1
Completed and
waiting on hook-up.
Valence Oper.
4 drilling wells and
2 Permits
Murray #1H
IP: 258Bbl/d, 106Mcf/d
Completed-
Jan ‘13
Cheyenne
Rockin S #1H
Completed 12-21-2012
CHK -
Avant D #1H
Suspended, waiting on
further completion work
CHK –
Brownlow #1H
Could not test
50
st
st


Pearsall Field Area Buda / Eagle Ford / Chalkleford Activity
51
Note: All acreage at April 9, 2013.  Well data from public information.


52
Adjusted EBITDA Reconciliation
This presentation includes, and certain statements made during this presentation may include, the non-GAAP
financial measure of Adjusted EBITDA.  We believe Adjusted EBITDA helps us evaluate our operating
performance
and
compare
our
results
of
operations
from
period
to
period
without
regard
to
our financing
methods or capital structure. We define Adjusted EBITDA as earnings before interest expense, income taxes,
depletion, depreciation and amortization, accretion of asset retirement obligations, property impairments,
unrealized derivative gains and losses, certain other non-cash items and non-cash stock-based compensation
expense,
including
stock
option
and
grant
expense
and
restricted
stock
and
restricted
stock
units
expense,
and net gain or loss on asset sales and inventory impairment. Adjusted EBITDA is not a measure of net (loss)
income or cash flows as determined by GAAP. Adjusted EBITDA should not be considered an alternative to,
or
more
meaningful
than,
net
income
or
cash
flows
from
operating
activities
as
determined
in
accordance
with
GAAP or as an indicator of our operating performance or liquidity.
The following tables present our calculation of Adjusted EBITDA and the reconciliation of Adjusted EBITDA
to
the
GAAP
financial
measures
of
net
(loss)
income
and
net
cash
provided
by
operating
activities,
respectively,
that
are
of
a
historical
nature.
Where
references
to
Adjusted
EBITDA
are
forward-looking,
prospective or estimates in nature, and not based on historical fact, the table does not provide a
reconciliation.  We could not provide such reconciliations without undue hardship because the Adjusted
EBITDA numbers included in this presentation, and that may be included in certain statements made during
the
presentation,
are
estimations,
approximations
and/or
ranges.
In
addition,
it
would
be
difficult
for
us
to
present a detailed reconciliation on account of many unknown variables for the reconciling items.


53
Adjusted EBITDA Reconciliation
The following table presents our calculation of Adjusted EBITDA and reconciliation of Adjusted EBITDA to the GAAP financial measures of net (loss)
income and cash provided by operating activities, respectively.
(In thousands)
2007
2008
2009
2010
2011
2012
Unaudited Adjusted EBITDA reconciliation to Net Income (Loss):
Net (loss) income
($300)
$103,878
($14,425)
$6,377
($10,309)
($33,261)
Interest expense
-
-
-
3
683
1,002
Total income tax provision (benefit)
-
20,023
(9,925)
3,521
(5,521)
(1,430)
Depletion, depreciation and amortization
7,889
12,127
10,743
15,596
31,754
80,454
Accretion of asset retirement obligations
70
92
137
155
209
256
Full-cost ceiling impairment
-
22,195
25,244
-
35,673
63,475
Unrealized loss (gain) on derivatives
211
(3,592)
2,375
(3,139)
(5,138)
4,802
Stock option and grant expense
205
605
622
824
2,362
(589)
Restricted stock grants
15
60
34
74
44
729
Net loss (gain) on asset sales and inventory impairment
-
(136,977)
379
224
154
485
Adjusted EBITDA
$8,090
$18,411
$15,184
$23,635
$49,911
$115,923
(In thousands)
2007
2008
2009
2010
2011
2012
Unaudited Adjusted EBITDA reconciliation to Net Cash Provided
by Operating Activities:
Net cash provided by operating activities
$7,881
$25,851
$1,791
$27,273
$61,868
$124,228
Net change in operating assets and liabilities
209
(17,888)
15,717
(2,230)
(12,594)
(9,307)
Interest expense
-
-
-
3
683
1,002
Current income tax provision (benefit)
-
10,448
(2,324)
(1,411)
(46)
-
Adjusted EBITDA
$8,090
$18,411
$15,184
$23,635
$49,911
$115,923
Year Ended December 31,
Year Ended December 31,


54
PV-10 Reconciliation
PV-10 is a non-GAAP financial measure and generally differs from Standardized Measure, the most
directly comparable GAAP financial measure, because it does not include the effects of income taxes on
future net revenues. PV-10 is not an estimate of the fair market value of our properties. Matador and others
in
the
industry
use
PV-10
as
a
measure
to
compare
the
relative
size
and
value
of
proved
reserves
held
by
companies
and
of
the
potential
return
on
investment
related
to
the
companies’
properties
without
regard
to
the specific tax characteristics of such entities. The PV-10 at December 31, 2008, December 31, 2009,
December 31, 2010, December 31, 2011, September 30, 2012 and December 31, 2012 may be reconciled
to the Standardized Measure of discounted future net cash flows at such dates by reducing PV-10 by the
discounted future income taxes associated with such reserves. The PV-10 at December 31, 2008,
December 31, 2009, December 31, 2010, December 31, 2011, September 30, 2012 and December 31,
2012
were,
in
millions,
$44.1,
$70.4,
$119.9,
$248.7,
$363.6
and
$423.2,
respectively.
The
discounted
future income taxes at December 31, 2008, December 31, 2009, December 31, 2010, December 31, 2011,
September 30, 2012 and December 31, 2012 were, in millions, $0.8, $5.3, $8.8, $33.2, $29.7 and $28.6,
respectively.