Document:

exv10w2

Exhibit 10.2

FORM OF ADMINISTRATION AGREEMENT

ADMINISTRATION AGREEMENT

BETWEEN

TPG SPECIALTY LENDING, INC.

AND

TSL ADVISERS, LLC

     This Agreement (“Agreement”) is made as of [MONTH] __, 2011 by and between TPG
SPECIALTY LENDING, INC. a Delaware corporation (the “Company”), and TSL ADVISERS, LLC, a
Delaware limited liability company (the “Administrator”).

     WHEREAS, the Company is a closed-end management investment fund that intends to elect to be
treated as a business development company (“BDC”) under the Investment Company Act of 1940
(the “Investment Company Act”);

     WHEREAS, the Company desires to retain the Administrator to provide administrative services to
the Company in the manner and on the terms hereinafter set forth; and

     WHEREAS, the Administrator is willing to provide administrative services to the Company on the
terms and conditions hereafter set forth;

     NOW, THEREFORE, in consideration of the premises and the covenants hereinafter contained and
for other good and valuable consideration, the receipt and adequacy of which is hereby
acknowledged, the Company and the Administrator hereby agree as follows:

1. Duties of the Administrator

          (a) Employment of Administrator. The Company hereby employs the Administrator to act
as administrator of the Company, and to furnish, or arrange for others to furnish, the
administrative services, personnel and facilities described below, subject to review by and the
overall control of the Board of Directors of the Company (the “Board”), for the period and
on the terms and conditions set forth in this Agreement. The Administrator hereby accepts such
employment and agrees during such period to render, or arrange for the rendering of, such services
and to assume the obligations herein set forth subject to the reimbursement of costs and expenses
provided for below. The Administrator and such others shall for all purposes herein be deemed to
be independent contractors and shall, unless otherwise expressly provided or authorized herein,
have no authority to act for or represent the Company in any way or otherwise be deemed agents of
the Company.

 

 

          (b) Services. The Administrator shall perform (or oversee, or arrange for, the
performance of) the administrative services necessary for the operation of the Company. Without
limiting the generality of the foregoing, the Administrator shall provide the Company with office
facilities, equipment, clerical, bookkeeping and record keeping services at such facilities and
such other services as the Administrator, subject to review by the Board, shall from time to time
determine to be necessary or useful to perform its obligations under this Agreement. The
Administrator shall also, on behalf of the Company, conduct relations with custodians,
depositories, transfer agents, dividend disbursing agents, other stockholder servicing agents,
accountants, attorneys, underwriters, brokers and dealers, corporate fiduciaries, insurers, banks
and such other persons in any such other capacity deemed to be necessary or desirable. The
Administrator shall make reports to the Board of its performance of obligations hereunder and
furnish advice and recommendations with respect to such other aspects of the business and affairs
of the Company as it shall determine to be desirable; provided that nothing herein shall be
construed to require the Administrator to, and the Administrator shall not, in its capacity as
Administrator pursuant to this Agreement, provide any advice or recommendation relating to the
securities and other assets that the Company should purchase, retain or sell or any other
investment advisory services to the Company. The Administrator shall be responsible for the
financial and other records that the Company is required to maintain and shall prepare, print and
disseminate reports to stockholders, and reports and other materials filed with the Securities and
Exchange Commission (the “SEC”). The Administrator will provide on the Company’s behalf
significant managerial assistance to those portfolio companies to which the Company is required to
provide such assistance. In addition, the Administrator will assist the Company in determining and
publishing (as necessary or appropriate) the Company’s net asset value, overseeing the preparation
and filing of the Company’s tax returns, and generally overseeing the payment of the Company’s
expenses and the performance of administrative and professional services rendered to the Company by
others.

2. Records

     The Administrator agrees to maintain and keep all books, accounts and other records of the
Company that relate to activities performed by the Administrator hereunder and will maintain and
keep such books, accounts and records in accordance with the Investment Company Act. In compliance
with the requirements of Rule 31a-3 under the Investment Company Act, the Administrator agrees that
all records which it maintains for the Company shall at all times remain the property of the
Company, shall be readily accessible during normal business hours, and shall be promptly
surrendered upon the termination of the Agreement or otherwise on written request. The
Administrator further agrees that all records which it maintains for the Company pursuant to Rule
31a-1 under the Investment Company Act will be preserved for the periods prescribed by Rule 31a-2
under the Investment Company Act unless any such records are earlier surrendered as provided above.
Records shall be surrendered in usable machine-readable form. The Administrator shall have the
right to retain copies of such records subject to observance of its confidentiality obligations
under this Agreement.

3. Confidentiality

     The parties hereto agree that each shall treat confidentially the terms and conditions of this
Agreement and all information provided by each party to the other regarding its business and

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operations. All confidential information provided by a party hereto, including nonpublic
personal information (regulated pursuant to Regulation S-P of the SEC), shall be used by any other
party hereto solely for the purpose of rendering services pursuant to this Agreement and, except as
may be required in carrying out this Agreement, shall not be disclosed to any third party, without
the prior consent of such providing party. The foregoing shall not be applicable to any
information that is publicly available when provided or thereafter becomes publicly available other
than through a breach of this Agreement, or that is required to be disclosed by any regulatory
authority, any authority or legal counsel of the parties hereto, by judicial or administrative
process or otherwise by applicable law or regulation.

4. Compensation; Allocation of Costs and Expenses

     In full consideration of the provision of the services of the Administrator, the Company shall
reimburse the Administrator for the costs and expenses incurred by the Administrator in performing
its obligations and providing personnel and facilities hereunder, it being understood and agreed
that, except as otherwise provided herein or in that certain Investment Advisory Management
Agreement, dated as of [   ], 2011 by and between the Company and the Adviser (the “Advisory
Agreement”), the Administrator shall be solely responsible for the compensation of its
investment professionals and employees and all overhead expenses of the Administrator (including
rent, office equipment and utilities). The Company will bear all costs and expenses that are
incurred in its operation, administration and transactions and not specifically assumed by the
Adviser pursuant to the Advisory Agreement. Costs and expenses to be borne by the Company include,
but are not limited to, those relating to: organizational expenses (up to an aggregate of
$1,500,000, it being understood and agreed that the Adviser shall bear all organizational expenses
of the Company in excess of such amount); calculating the Company’s net asset value (including the
cost and expenses of any independent valuation firm); expenses incurred by the Adviser payable to
third parties, including agents, consultants or other advisors, in monitoring financial and legal
affairs for the Company and in providing administrative services, monitoring the Company’s
investments and performing due diligence on its prospective portfolio companies; interest payable
on debt, if any, incurred to finance the Company’s investments; sales and purchases of the
Company’s common stock and other securities; investment advisory and management fees;
administration fees, if any, payable under this Agreement; fees payable to third parties, including
agents, consultants or other advisors, relating to, or associated with, evaluating and making
investments; transfer agent and custodial fees; federal and state registration fees; all costs of
registration and listing the Company’s shares on any securities exchange; federal, state and local
taxes; independent directors’ fees and expenses; costs of preparing and filing reports or other
documents required by the SEC; costs of any reports, proxy statements or other notices to
stockholders, including printing and mailing costs and the costs of any stockholders’ meetings, as
well as the compensation of an investor relations professional responsible for the coordination and
administration of the foregoing; the Company’s allocable portion of the fidelity bond, directors
and officers/errors and omissions liability insurance, and any other insurance premiums; direct
costs and expenses of administration, including printing, mailing, long distance telephone,
copying, secretarial and other staff, independent auditors and outside legal costs; compensation of
other professionals (including employees of the Administrator) devoted to preparing the Company’s
financial statements or tax returns or providing similar “back office” financial services to the
Company; and all other expenses incurred by the Company or the Administrator in connection with
administering the

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Company’s business. Notwithstanding anything to the contrary contained herein, the Company
shall reimburse the Adviser (or its affiliates) for an allocable portion of the compensation paid
by the Adviser (or its affiliates) to the Company’s Chief Compliance Officer and Chief Financial
Officer (based on a percentage of time such individuals devote, on an estimated basis, to the
business and affairs of the Company). For the avoidance of doubt, the Adviser shall be solely
responsible for any placement or “finder’s” fees payable to placement agents engaged by the Company
or its affiliates in connection with the offering of securities by the Company.

5. Limitation of Liability of the Administrator; Indemnification

     The Administrator (and its members, managers, officers, employees, agents, controlling persons
and any other person or entity affiliated with it) shall not be liable to the Company for any
action taken or omitted to be taken by the Administrator in connection with the performance of any
of its duties or obligations under this Agreement or otherwise as administrator for the Company.
As permitted by Article VIII of the Certificate of Incorporation, the Company shall, to the fullest
extent permitted by law, provide indemnification and the right to the advancement of expenses, to
each person who was or is made a party or is threatened to be made a party to or is involved
(including, without limitation, as a witness) in any actual or threatened action, suit or
proceeding, whether civil, criminal, administrative or investigative, by reason of the fact that
he/she is or was a member, manager, officer, employee, agent, controlling person or any other
person or entity affiliated with the Administrator (each such person hereinafter an
“Indemnitee”), on the same general terms set forth in Article VIII of the Certificate of
Incorporation, the terms of which are incorporated herein mutatis mutandi as applied to the
Indemnitees.

6. Activities of the Administrator

     The services of the Administrator to the Company are not to be deemed to be exclusive, and the
Administrator and each affiliate is free to render services to others. It is understood that
directors, officers, employees and stockholders of the Company are or may become interested in the
Administrator and its affiliates, as directors, officers, members, managers, employees, partners,
stockholders or otherwise, and that the Administrator and directors, officers, members, managers,
employees, partners and stockholders of the Administrator and its affiliates are or may become
similarly interested in the Company as stockholders or otherwise.

7. Duration and Termination of this Agreement

          (a) This Agreement shall continue in effect for two years from the date hereof, and thereafter
shall continue automatically for successive annual periods, provided that such continuance is
specifically approved at least annually by:

               (i) the vote of the Board, or by the vote of a majority of the outstanding voting securities
of the Company; and

               (ii) the vote of a majority of the Company’s directors who are not parties to this Agreement
or “interested persons” (as such term is defined in Section 2(a)(19) of the Investment Company Act)
of any such party, in accordance with the requirements of the Investment Company Act.

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          (b) The Agreement may be terminated at any time, without the payment of any penalty, upon not
more than 60 days’ written notice, by the vote of a majority of the outstanding voting securities
of the Company, or by the vote of the Board or by the Administrator.

          (c) This Agreement may not be assigned by a party without the consent of the other
party; provided, however, that the rights and obligations of the Company
under this Agreement shall not be deemed to be assigned to a newly formed entity in the
event of the merger of the Company into, or conveyance of all of the assets of the Company
to, such newly formed entity; provided, further, however, that the
sole purpose of that merger or conveyance is to effect a mere change in the Company’s legal
form into another limited liability entity. The provisions of Section 5 of this Agreement
shall remain in full force and effect, and the Administrator shall remain entitled to the
benefits thereof, notwithstanding any termination of this Agreement.

8. Amendments of this Agreement 

     This Agreement may be amended pursuant to a written instrument by mutual consent of the
parties.

9. Governing Law

     This Agreement shall be construed in accordance with the laws of the State of Delaware and the
applicable provisions of the Investment Company Act, if any. In such case, to the extent the
applicable laws of the State of Delaware, or any of the provisions herein, conflict with the
provisions of the Investment Company Act, the latter shall control.

10. Entire Agreement

     This Agreement contains the entire agreement of the parties and supercedes all prior
agreements, understandings and arrangements with respect to the subject matter hereof.

11. Notices

     Any notice under this Agreement shall be given in writing, addressed and delivered or mailed,
postage prepaid, to the other party at its principal office.

Remainder of Page Intentionally Left Blank

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     IN WITNESS WHEREOF, the parties hereto have executed and delivered this Agreement as of the
date first above written.

	 	 	 	 	 
	 	TPG SPECIALTY LENDING, INC.

 	 
	 	By:  	 	 
	 	 	Name:  	 	 
	 	 	Title:  	 	 
	 

	 	 	 	 	 
	 	TSL ADVISERS, LLC

 	 
	 	By:  	 	 
	 	 	Name:  	 	 
	 	 	Title:exv10w1

Exhibit 10.1

PRR 0029-000

GAS PURCHASE CONTRACT

Between APPROACH OPERATING, LLC as Seller

And DCP MIDSTREAM, LP as Buyer

Dated January 1, 2011

INDEX

	 	 	 	 	 	 	 
	SECTION	 	PAGE	 
	 
	 	 	 	 	 	 
	1.
	 	COMMITMENT	 	 	1	 
	2.
	 	DELIVERY POINTS	 	 	2	 
	3.
	 	DELIVERY PRESSURE	 	 	2	 
	4.
	 	QUANTITY	 	 	3	 
	5.
	 	PRICE	 	 	4	 
	6.
	 	TERM	 	 	7	 
	7.
	 	ADDRESSES AND NOTICES	 	 	7	 
	8.
	 	CONFIDENTIALITY	 	 	8	 
	9.
	 	SIGNATURE PAGE	 	 	9	 
	 
	 	 	 	 	 	 
	EXHIBIT A

	GENERAL TERMS AND CONDITIONS

	 
	 	 	 	 	 	 
	A.
	 	DEFINITIONS	 	 	A-1	 
	B.
	 	DELIVERY DATE; COMPRESSION	 	 	A-1	 
	C.
	 	RESERVATIONS OF SELLER	 	 	A-2	 
	D.
	 	METERING AND MEASUREMENT	 	 	A-2	 
	E.
	 	DETERMINATION OF GAS COMPOSITION, GRAVITY, AND HEATING VALUE	 	 	A-3	 
	F.
	 	QUALITY OF GAS	 	 	A-3	 
	G.
	 	BILLING AND PAYMENT	 	 	A-4	 
	H.
	 	FORCE MAJEURE	 	 	A-4	 
	I.
	 	WARRANTY OF TITLE	 	 	A-5	 
	J.
	 	ROYALTY AND OTHER INTERESTS	 	 	A-5	 
	K.
	 	SEVERANCE AND SIMILAR TAXES	 	 	A-5	 
	L.
	 	INDEMNIFICATION AND RESPONSIBILITY FOR INJURY OR DAMAGE	 	 	A-5	 
	M.
	 	RIGHT OF WAY	 	 	A-5	 
	N.
	 	ASSIGNMENT	 	 	A-6	 
	O.
	 	MISCELLANEOUS PROVISIONS	 	 	A-6	 

EXHIBIT B COMMITTED AREAS AND DELIVERY POINTS

 

 

PRR 0029-000

GAS PURCHASE CONTRACT

     This Contract is entered as of January 1, 2011, among APPROACH RESOURCES I, LP, APPROACH OIL &
GAS INC. (collectively “Seller”) and DCP MIDSTREAM, LP (“Buyer”).

     In consideration of the mutual covenants contained herein, the parties agree as follows:

     1. COMMITMENT. (a) Committed Lands and Leases. Seller commits to this
Contract and will sell and deliver and Buyer will purchase and receive the gas produced from all
wells now or later located on all oil and gas interests now or later owned or controlled by Seller
on or allocated to the following lands in Crockett and Schleicher Counties, Texas:

The Block 54 acreage shaded in blue, the Cinco Terry acreage shaded in pink, the
Northeast Ozona acreage shaded in purple, the new acreage shaded in yellow to the
extent not covered by the Preferential Right (defined below) held by WTG (defined
below), and the additional acreage shaded in gray, all as shown on the Exhibit B-1
Map.

Buyer also commits to receive, gather, and process Seller’s gas delivered hereunder for extraction
of NGLs in accordance with this Contract. Definitions and General Terms and Conditions included in
this Contract are attached as Exhibit A. All Exhibits referenced herein are attached and
incorporated by reference. In the event of any conflict between this Contract and the Exhibits,
this Contract shall govern.

     (b) Cinco Terry Acreage. The Cinco Terry acreage shown on the Exhibit B-1 Map and
shaded in pink is subject to an existing prior commitment to WTG Benedum Joint Venture (“WTG”) that
expires as of November 30, 2012. Deliveries from the Cinco Terry acreage under this Contract will
not commence prior to that date unless Seller’s prior commitment to WTG does not apply. WTG also
holds an option to extend the prior commitment under its existing gas Purchase Agreement dated as
of November 21, 2007, as amended June 3, 2009, among Approach Oil & Gas Inc., Approach Operating,
LLC, and WTG (“Preferential Right”). Buyer has an existing pipeline that extends northwest from
Buyer’s present gathering system to the contemplated new Delivery Point for the Cinco Terry
acreage, indicated in red in the Exhibit B-1 map (“FinTex Line”). The FinTex Line is presently
idle, and Buyer must review its integrity by hydrotesting and must secure its rights of way and
other realty rights relating to the FinTex Line prior to resuming its operation. Buyer will
conduct its hydrotest and review of realty rights for the FinTex Line substantially in advance of
November 30, 2012, and in any event no later than March 31, 2011. If the hydrotest or review of
realty rights indicates that resumption of operations using the FinTex Line is not economically
feasible, Buyer will construct or otherwise secure a replacement line and Delivery Point, which may
not be in the same location, but which will be in a

 

 

location reasonably acceptable to Seller, to support deliveries of gas from the Cinco Terry acreage
under this Contract. Seller will give timely notice to WTG that Seller is terminating its contract
with WTG as of November 30, 2012. If WTG validly exercises its Preferential Right to extend its
contract with Seller, Seller’s commitment of the Cinco Terry acreage under this Contract will
terminate. If WTG does not validly exercise its Preferential Right, Seller’s commitment of the
Cinco Terry acreage under this Contract will apply and be effective as of December 1, 2012.

     (c) Northeast Ozona Acreage. The Northeast Ozona acreage shown on the Exhibit B-1 Map
and shaded in purple is subject to a prior commitment to Ozona Pipeline Energy Company (“Ozona”),
and Ozona then has contracted with Buyer for processing of the Northeast Ozona acreage gas
production. Seller and Buyer each agree to terminate their respective commitments with Ozona as
they relate to the Northeast Ozona acreage effective no later than the close of business on March
31, 2011. Buyer’s and Seller’s commitment relating to the Northeast Ozona acreage shown on
Exhibit B-1 shall not become effective until April 1, 2011, or sooner if Seller is able to obtain
an earlier termination of its commitment to Ozona.

     2. DELIVERY POINTS. The Delivery Points for gas to be delivered by Seller to Buyer
will be at the inlets of Buyer’s Facilities at the three locations shown on Exhibit B-1 and
described in Exhibit B-2. Seller is responsible for connecting all production from the committed
area and gathering it to these three Delivery Points. Buyer will install, own, and operate the
connecting pipeline from its existing system to the three Delivery Points and the Delivery Points
meter stations. Seller shall retain title to the NGLs content of the gas delivered by Seller until
they are extracted at the plant and available for sale. Seller will then sell its NGLs to Buyer at
the plant tailgate as more fully stated in Section 5, Price. Title to the remainder of the gas and
all its components shall pass to and vest in Buyer at the Delivery Points without regard to the
purposes for which Buyer may later use or sell the gas or its components.

     3. DELIVERY PRESSURE. Subject to the reservations of Seller in Section C of Exhibit A,
Seller will deliver the gas at the Delivery Points at a pressure sufficient to enable it to enter
Buyer’s Facilities against the working pressure at reasonably uniform rates of delivery, not to
exceed the maximum allowable operating pressure of 1200 psia established by Buyer or pressures that
prevent others from producing ratably. Buyer in its discretion may require that Seller install and
operate a pressure relief or reduction device upstream of any Delivery Point set at the pressure
designated by Buyer to limit the pressure at which Seller delivers gas, where Seller’s deliveries
might interfere with ratable deliveries from others, or to enhance safety.

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     4. QUANTITY. (a) Seller shall deliver and Buyer shall purchase and take Seller’s gas
subject to the operating conditions and capacity of Buyer’s Facilities. Buyer will use
commercially reasonable efforts to market gas for resale and operate its facilities in an effort to
maintain consistent takes of all available quantities. If Buyer is unable to take the full
quantities available, Buyer will use commercially reasonable efforts to purchase gas from the lands
covered by this Contract ratably with its purchases of similar gas in each common gathering system
or area within its capabilities using existing facilities, in compliance with Buyer’s existing
contracts and with applicable laws and regulations, including ratable purchases from Buyer’s
Affiliates. Within the capabilities of Buyer’s Facilities, Seller will deliver and Buyer will take
gas from all committed areas in reasonably consistent daily quantities. All gas and NGLs purchased
from Seller shall be purchased and allocated using the applicable provisions of Sections 5.1, 5.2,
5.4 and 5.6 of this Contract.

     (b) Seller may dispose of any gas not taken by Buyer for any reason, including events of force
majeure, subject to Buyer’s right to resume purchases at any subsequent time. If Buyer does not
take gas for 15 consecutive Days and Seller secures a different temporary market, Buyer may resume
purchases only upon 15 Days’ advance written notice as of the beginning of a month unless otherwise
agreed.

     (c) Seller will use commercially reasonable efforts to deliver gas meeting the quality
requirements of Exhibit A, Section F.1 and to avoid delivery of Inferior Liquids. If the gas at
any Delivery Point becomes insufficient in volume (under Section 5.5), quality (under Exhibit A,
Section F.1), or pressure (under Section 3), Buyer may cease gas takes from the Delivery Point
upon 15 Days’ advance written notice to Seller as long as the condition exists. If Buyer ceases
taking gas under this Section for 30 consecutive Days for reasons other than quality or Force
Majeure, Seller may terminate this Contract with respect to the affected Delivery Points upon 30
Days’ advance written notice to Buyer; provided that during the notice period Buyer may resume full
takes and purchases, and thereby avoid Contract termination under Seller’s notice. If Buyer
disconnects the Delivery Point or removes the measurement device, meter tube and/or other equipment
(which Buyer shall only do on 15 Days’ advance written notice to Seller) and Seller later delivers
a written request to Buyer to reconnect the Delivery Point, then within 30 Days after receipt of
Seller’s notice, Buyer shall either reconnect the Delivery Point or terminate this Contract as to
any affected Delivery Points by 15 Days’ advance written notice to Seller. If Buyer elects to
reconnect the Delivery Point, before Buyer makes the reconnection, Seller shall pay to Buyer the
fee that Buyer then charges for similar reconnections.

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     5. PRICE.

     5.1 Consideration. As full consideration for Seller’s gas and all its components
delivered to Buyer each month, Buyer shall pay Seller (a) the applicable percentage under Table 5.1
below of the net Residue Gas value under Section 5.2 for Residue Gas allocated to Seller’s gas, and
(b) the applicable percentage under Table 5.1 of the net value under Section 5.4 for any recovered
NGLs allocated to Seller’s gas. No separate payment or value calculation is to be made under this
Contract for helium, sulfur, CO2, other non-hydrocarbons, or for Inferior Liquids.

Table 5.1

	 	 	 
	Month’s Total Contract	 	 
	Average Mcf/Day	 	Applicable Percentages
	> 7,000

≤ 7,000
	 	95% / 95%

93% / 93%

     5.2 Residue Gas Value. (a) The net Residue Gas value will be the month’s average of
each day’s Platts Gas Daily mid-point prices posted for the delivery month for “Daily Price Survey”
Permian Basin Area — Waha (“Daily Index Price”), less $0.06 per MMBtu.

     (b) If the Index Price or Daily Index Price quotation is discontinued or materially modified,
its successor shall be used, or in the absence of a successor, Buyer and Seller shall promptly
select another publication that enables calculation of an Index Price or Daily Index Price closely
comparable to that previously used. If the Daily Index Price is discontinued or materially
modified, Buyer or Seller will inform the other party by written notice, stating its proposed
changes and the reason for the changes.

     5.3 NGL Marketing Option. Seller has reserved title to the NGLs extracted from
Seller’s gas under Section 2 above. Seller shall take its NGLs in kind at the plant tailgate of
the plant where processing occurs. Seller elects to sell to Buyer, and Buyer agrees to purchase,
market, and sell, the NGLs taken in kind by Seller attributable to Seller’s gas at the Plant
tailgate for the consideration stated in this Section 5.

     5.4 (a) NGL Value. The net value of NGLs attributable to Seller will be the simple
average of the midpoint of the daily high/low spot price for (i) purity ethane, (ii) non-TET
propane, (iii) non-TET isobutane, (iv) non-TET normal butane, and (v) non-TET natural gasoline
(pentanes and heavier) during the month as reported for Mont Belvieu, Texas published by the Oil
Price Information Service (or in its absence, a comparable successor publication designated by
Buyer and agreed by Seller) less Buyer’s actual reasonable TF&S costs relating to the movement to
and disposition of Seller’s NGLs using transportation on the E-Z and other NGL lines for deliveries
to Sweeny, Texas, Mont Belvieu,

-4-

 

Texas, or other similarly-priced fractionator market centers mutually agreed by both parties,
and less a $0.0025/gallon NGL marketing fee. For purposes of these TF&S cost calculations, Buyer
will use a cost and volume weighting of 50% each for costs incurred for NGL handling downstream
from (i) the Buyer-operated Ozona Gas Plant and (ii) Buyer’s Southwest Ozona Gas Plant. If a
change in downstream NGL pipeline specifications causes a failure to meet the revised NGLs quality
specifications and Buyer incurs NGL off quality fees as a result, Buyer will so notify Seller, and
the parties shall then negotiate an equitable solution of the problem. Seller recognizes that
Affiliates of Buyer may be involved in handling NGLs downstream from the Plant, and acknowledges
that the reasonable good faith prices or fees so established will nevertheless control.

     (b) Alternate NGLs Pricing for Force Majeure Events. Notwithstanding the other
provisions of this Section 5, during and following a hurricane or other event of Force Majeure or
an inability to market NGLs on resale due to lack of available NGL pipeline or fractionation
capacity that affects Buyer’s NGLs resale markets, Buyer may elect in view of the resulting supply
or market volatility that Seller’s NGLs be priced (i) using Seller’s pro rata share of actual NGLs
recoveries in lieu of the fixed recoveries provided in Section 5.6 below, and (ii) using the actual
NGLs prices that Buyer received on resale in lieu of OPIS pricing under subsection (a) above.
Buyer shall provide Seller prompt information on any alternate pricing election under this
subsection. Alternate pricing under this subsection will expire when Buyer’s NGLs resale markets
have, in the reasonable determination of Buyer and Seller, recovered from the effects of the Force
Majeure event to the extent that buyer is able to resume normal NGLs resales reasonably free from
market distortions caused by the Force Majeure event and without NGLs resale capacity restraints.

     (c) Force Majeure Termination. Notwithstanding any other provision in this Contract
to the contrary, if as a result of one or more incidents of Force Majeure Buyer is unable to accept
and purchase all of Seller’s gas committed hereunder, or if Buyer is unable to market and sell all
of the NGLs extracted from such gas, each at the full price set forth in this Section 5, and the
cumulative period of Force Majeure exceeds 225 cumulative Days during the primary term or 45
cumulative Days during any renewal term, then Seller, upon providing documentation, shall have the
right to terminate this Contract as of the end of a month upon 15 Days written notice to Buyer.

     5.5 Low Volume Delivery Points. Whenever the month’s volume delivered to Buyer at any
Delivery Point is less than 450 Mcf, Buyer will charge Seller a low volume fee of $300.00 per low
volume month per affected Delivery Point. Buyer may deduct this fee from any proceeds payable to
Seller or may invoice Seller for the amount due, to be paid by Seller within 20 Days of the invoice
date. Seller may cease application of low volume fees under this Section by giving Buyer 30 Days
advance

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written notice of Seller’s request to have the affected meters disconnected. The low volume
fees will no longer apply as of the end of the notice period, and Buyer may disconnect the affected
meters.

     5.6 Allocation of Residue Gas and NGLs. Buyer will determine the residue gas and NGLs
attributable to Seller using the following definitions and procedures. From time to time Buyer may
make changes and adjustments in its allocation methods to improve accuracy or efficiency.

a. Delivery Point Volume. The Delivery Point Volume will be the quantity of
gas delivered by Seller to Buyer at the inlets of Buyer Facilities at the Delivery
Points.

b. Seller’s Plant Inlet Volume. Seller’s Plant Inlet Volume in MMBtu is
Seller’s Delivery Point Volume in MMBtu less 1% for field fuel and line loss.

c. Determination of NGL Volumes. Buyer will determine the quantity of each
NGL component attributable to Seller’s gas by multiplying Seller’s Plant Inlet
Volume in Mcf by the gallons of each component contained in the gas delivered by
Seller at each Delivery Point by the following fixed recovery percentages:

	 	 	 	 	 

	Ethane
	 	 	80	%
	Propane
	 	 	95	%
	Iso & Normal Butanes
	 	 	97	%
	Pentanes & Heavier
	 	 	97	%

d. Residue Gas Attributable to Seller. The MMBtus of Residue Gas
attributable to Seller will be the sum of the MMBtus of methane and heavier
hydrocarbons contained in the Seller’s Plant Inlet Volume, less the MMBtus contained
in the NGL gallons allocated to Seller’s gas under 5.5(c) above using the
industry-accepted Btu/gallon content for each NGL component, and less 3% of Seller’s
Plant Inlet Volume in MMBtus as a deduction for plant fuel, losses, and
unaccountables.

e. Force Majeure, Maintenance. Whenever Force Majeure or maintenance needs
prevent normal gathering or processing operations for Seller’s gas for more than 10
days in any calendar month, Buyer may elect to allocate Seller’s attributable NGL
gallons and Residue Gas will be based on Seller’s proportional share of actual
gathering and processing results during those periods. Buyer will include the
adjusted overall monthly recoveries in its monthly gas statement to Seller.

     5.7 Unprofitable Situations. (a) Notwithstanding the foregoing provisions
of this Section 5, if at any time, and from time to time, Buyer reasonably demonstrates through
information provided to Seller that its taking and handling of gas from any or all Delivery Points
under this Contract are or are about to become unprofitable to Buyer, Buyer may notify Seller of
Buyer’s intent to renegotiate Seller’s Table 5.1 percentages as to all or certain affected Delivery
Points, upon at least 90 Days advance written notice from buyer to Seller prior to the proposed
effective date of the change, which shall be as of the first of a month. If Buyer proposes a
different Table 5.1 percentage and Seller is not willing to accept the percentage nominated by
Buyer as reasonable, then as to all gas affected by Buyer’s notice for which the parties do not
agree, Seller shall have the right to terminate this Contract upon written

-6-

 

notice to Buyer. Buyer agrees not to exercise this right during the first 36 months of the
term of this Contract.

     (b) If this Contract is terminated in its entirety or with respect to the committed acreage
upstream of any Delivery Point pursuant to this Section 5.7, Buyer shall be obligated to offer to
enter into a written agreement with Seller to receive the gas produced form the acreage affected by
the termination at the applicable Delivery Point and redeliver thermally equivalent quantities
(less actual fuel and line loss not to exceed 5%) to the tailgate of the plant. Buyer’s offer must
be made in writing within five (5) business Days of such termination and remain open for acceptance
by Seller for a period of at least ten (10) business Days after the offer is made.

     6. TERM. This Contract shall be in force from and after its execution and shall remain
in effect for a primary term expiring five (5) years following the last Day of the month in which
this Contract is executed, and will continue in effect from year to year thereafter until canceled
by either party as of the end of the primary term or as of any anniversary thereafter by giving the
other party at least 60 Days’ but no more than 120 Days’ advance written notice of termination.

     7. ADDRESSES AND NOTICES. Either party may give notices to the other party by first
class mail postage prepaid, by overnight delivery service, or by facsimile with receipt confirmed
at the following addresses or other addresses furnished by a party by written notice. Unless
Seller objects in writing, Buyer may also use Seller’s current address for payments. Any telephone
numbers below are solely for information and are not for Contract notices. The parties opt out of
electronic delivery of notices and amendments under this Contract, except that notices and
hand-signed amendments may be delivered by facsimile with receipt confirmed as stated above.

	 	 	 

	Notices to Seller — Correspondence
	 	Approach Resources I, LP / Approach Oil & Gas Inc.
	 
	 	Attn:  Gas Contract Administration
	 
	 	6500 West Freeway, Suite 800
	 
	 	Fort Worth, TX  76116
	 
	 	Phone: (817) 989-9000
	 
	 	Fax: (817) 989-9001
	 
	 	 
	Notices to Seller — Payments:
	 	To the bank and account that Seller
will furnish to Buyer’s Division Orders office.
	 
	 	 
	Notices to Buyer — Billings & Statements:
	 	DCP Midstream, LP
	 
	 	Attn: Revenue Accounting
	 
	 	5718 Westheimer Road, Suite 1900
	 
	 	Houston, TX  77057
	 
	 	Phone (713) 735-3600
	 
	 	Fax:  (713) 735-3149

-7-

 

	 	 	 

	Notices to Buyer — Division Orders:
	 	DCP Midstream, LP
	 
	 	Attn: Division Orders
	 
	 	6120 S. Yale, Suite 1100
	 
	 	Tulsa, OK  74136
	 
	 	Phone: (918) 524-0944
	 
	 	Fax: (918) 524-0997
	 
	 	 
	Buyer — Correspondence
	 	DCP Midstream, LP
	 
	 	Attn: Contract Administration
	 
	 	10 Desta Drive, Suite 400-West
	 
	 	Midland, TX  79705
	 
	 	Phone:
(432) 620-4000
	 
	 	Fax: (432) 620-4160

     8. CONFIDENTIALITY. Except as provided below, the parties shall not disclose to any
third party and shall maintain strict confidentiality of all terms of this Contract and all matters
relating to its negotiation throughout its term. Notwithstanding the foregoing, the parties shall
be permitted to disclose the existence and terms of this Contract (1) to WTG to the extent
necessary to comply with the WTG Preferential Right, (2) to their respective members, managers,
directors, partners, officers, employees, agents, advisors (including without limitation, Seller’s
financial and engineering advisors, counsel, consultants, bankers and accountants), lenders,
investors, strategic partners who agree to keep this information confidential, and Other WI Gas
owners, royalty owners and (3) pursuant to any law, rule or regulation or order of a court or
regulatory body of competent jurisdiction, or as required by applicable securities law and
regulations or stock exchange on which it securities or those of an Affiliate are listed; provided,
that in the event of disclosure under subparagraph (3), the disclosing party shall use commercially
reasonable efforts to advise and consult with the other party prior to any such disclosure. The
parties’ confidentiality obligations will not apply to information that a disclosing party can
demonstrate (a) is or becomes generally available to the public other than as a result of a
disclosure by the disclosing party in violation of this Agreement, (b) was within the disclosing
party’s possession prior to being furnished to such party pursuant to this Contract, provided that
the source of such information was not bound by a confidentiality agreement or other contractual,
legal, or fiduciary obligation of confidentiality with respect to such information, or (c) becomes
available to the disclosing party on a non-confidential basis from a source other than the other
party to this Contract, provided that such source is not bound by a confidentiality agreement with
or other contractual, legal or fiduciary obligation of confidentiality with respect to such
information.

-8-

 

     The parties have signed this Contract by their duly authorized representatives as of the date
first stated above.

	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 

	APPROACH RESOURCES I, LP	 	 	 	DCP MIDSTREAM, LP	 	 
	By:	 	APPROACH OPERATING, LLC	 	 	 	 	 	 	 	 	 	 
	 	 	General Partner	 	 	 	 	 	 	 	 	 	 
	By:	 	APPROACH RESOURCES INC.	 	 	 	 	 	 	 	 	 	 
	 	 	Sole Member	 	 	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	By:	 	J. Ross Craft	 	 	 	By:	 	/s/ Richard Cargile	 	 
	 	 	 	 	 	 	 	 	 	 	 
	 	 	J. Ross Craft	 	 	 	 	 	Richard Cargile	 	 
	 	 	President and CEO	 	 	 	 	 	President, Western Business Unit	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Signed on:	 	12/28/2010	 	 	 	Signed on:	 	1/10/2011	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 
	 
	 	 	 	Seller	 	 	 	 	 	 	 	Buyer	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	APPROACH OIL & GAS INC.	 	 	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	By:	 	J. Ross Craft	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	J. Ross Craft, President
and CEO	 	 	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Signed on:	 	12/28/2010	 	 	 	 	 	 	 	 	 	 
	 
	 	 	 	 	 	 	 	 	 	 	 	 	 
	 
	 	 	 	Seller	 	 	 	 	 	 	 	 	 	 

Signature Sheet for Gas Purchase

Contract dated January 1, 2011

-9-

 

EXHIBIT A to GAS PURCHASE CONTRACT between

APPROACH RESOURCES I, LP and APPROACH OIL & GAS INC. as Seller and

DCP MIDSTREAM, LP as Buyer

Dated as of January 1, 2011

GENERAL TERMS & CONDITIONS

A. DEFINITIONS

Except where the context indicates a different meaning or intent, and whether or not
capitalized, the following terms will have meanings as follows:

(a) Affiliate — a company (i) in which a party owns directly or indirectly 50% or more of
the issued and outstanding voting stock or other equity interests; (ii) which owns directly or
indirectly 50% or more of the issued and outstanding voting stock or equity interests of the party;
and (iii) in which a company described in (ii) owns, directly or indirectly, 50% or more of the
issued and outstanding voting stock or other equity interests.

(b) Btu — British thermal unit. MMBtu — one million Btus.

(c) Buyer’s Facilities — the gas delivered by Seller will be gathered in gathering systems
and may be redelivered to a gas processing plant or plants for the removal of NGLs together with
gas produced from other properties. The gathering systems and plant or plants, or successor
facilities, are “Buyer’s Facilities” whether owned by Buyer, an Affiliate of Buyer, or an
unaffiliated third party. No facilities downstream of the processing plant or plants other than
short connecting lines to transmission lines are included in “Buyer’s Facilities.”

(d) Day — a period of 24 consecutive hours beginning and ending at 9:00 a.m. local time,
or other 24 hour period designated by Buyer and a downstream pipeline.

(e) Delivery Points — whether one or more, see Sections 2, B.1, and B.2.

(f) Force Majeure — see Section H.2 below.

(g) Gas or gas — all natural gas that arrives at the surface in the gaseous phase,
including all hydrocarbon and non-hydrocarbon components, casinghead gas produced from oil wells,
gas well gas, and stock tank vapors.

(h) GPM — NGL gallons per Mcf.

(i) Inferior Liquids — Mixed crude oil, slop oil, salt water, nuisance liquids, and other
liquids recovered by Buyer in its gathering system or at plant inlet receivers. Buyer will retain
revenues from Inferior Liquids, drips, and other gathering system liquids to defray costs of
treating and handling; Buyer will not allocate or pay for those liquids.

(j) Mcf — 1,000 cubic feet of gas at standard base conditions of 60oF and 14.73 psia.

(k) MMcf — 1,000 Mcf.

(l) Month or month — a calendar month beginning on the first Day of a Month.

(m) NGL or NGLs — natural gas liquids, or ethane and heavier liquefiable
hydrocarbons separated from gas and any incidental methane in NGL after processing.

(n) Preferential Right —  the preferential right in favor of WTG as defined in Section
1(b).

(o) psi — pounds per square inch; psia — psi absolute; psig — psi gauge.

(p) Residue Gas — merchantable hydrocarbon gas available for sale from Buyer’s Facilities
remaining after processing, and hydrocarbon gas resold by Buyer without first being processed.

(q) TET — price quotes for NGL on the Texas Eastern Products Pipeline Company, LLC system.

(r) TF&S — NGL transportation, fractionation, and storage.

B. DELIVERY DATE; COMPRESSION

B.1 Connected Sources Delivery Date. As to committed sources of production already
connected to Buyer’s Facilities, deliveries under this Contract will commence as of the date of
completion of Buyer’s needed Facilities improvements and readiness for service as to each Delivery
Point.

B.2 Additional Sources. As to sources not yet connected, Seller will commence and complete
with due diligence the construction of the facilities necessary to enable Seller to deliver the
committed gas at the Delivery Points, and Buyer will cause prompt commencement and complete with
due diligence construction of the facilities necessary and economically feasible in Buyer’s sole
discretion to enable Buyer or its gas gathering contractor to receive deliveries of gas at the
Delivery Points. If Buyer determines it is not economically feasible to construct the facilities,
Seller will have the option to construct facilities necessary to deliver gas into Buyer’s then
existing facilities. If neither Buyer nor Seller elect to construct the necessary facilities,
either party may cancel this Contract as to the affected gas upon 30 Days advance written notice to
the other.

B.3 Options to Compress. Seller is obligated to provide compression to deliver gas into
Buyer’s facilities at the Delivery Points.

 

 

C. RESERVATIONS OF SELLER

C.1 Reservations. Seller reserves the following rights with respect to its interests
in the oil and gas properties committed by Seller to Buyer under this Contract together with
sufficient gas to satisfy those rights:

(a) To operate the oil and gas properties free from control by Buyer as Seller in Seller’s sole
discretion deems advisable, including without limitation the right, but never the obligation, to
drill new wells, to repair and rework old wells, renew or extend, in whole or in part, any oil and
gas lease covering any of the committed properties, and to abandon any well or surrender any oil
and gas lease, in whole or in part, when Seller no longer deems it capable of producing gas in
paying quantities under normal methods of operation.

(b) To use gas for developing and operating the committed oil and gas properties and to fulfill
obligations to Seller’s lessors for those properties.

(c) To pool, combine, and unitize any of Seller’s oil and gas properties with other properties in
the same field, and to alter pooling, combinations, or units; this Contract will then cover
Seller’s allocated interest in unitized production insofar as that interest is attributable to the
oil and gas properties committed under this Contract, and the description of the property committed
will be considered to have been amended accordingly.

(d) To retain oil and liquid hydrocarbons separated from the gas, prior to delivery to Buyer at the
Delivery Point(s), by the use of conventional mechanical separators.

C.2 Exception. Subject to Section C.1, Seller will not engage in any operation, including
without limitation reinjection, recycling, or curtailment, that would materially reduce the amount
of gas available for sale to Buyer except upon 60 Days advance written notice to Buyer, or as much
advance notice as is feasible under the circumstances.

D. METERING AND MEASUREMENT

D.1 Buyer to Install Meters. Buyer will own, maintain, and operate orifice meters or
other measuring devices of standard make at or near the Delivery Points. Except as otherwise stated
in this Section D, Buyer will install orifice meters or other measurement devices and compute
volumes in accordance with accepted industry practice. Buyer may re-use metering equipment not
meeting current standards but meeting 1985 or later published standards for gas sources not
expected to deliver in excess of 100 Mcf per Day. A party providing compression facilities will
also provide sufficient pulsation dampening equipment customary to the industry to prevent
pulsation from affecting measurement at the Delivery Points. This equipment will not unreasonably
be requested. The parties may use electronic recording devices. Seller will have access to
Buyer’s metering equipment at reasonable hours, but only Buyer will calibrate, adjust, operate, and
maintain it.

D.2 Unit of Volume. The unit of volume will be one cubic foot of gas at a base temperature
of 60° F. and at a pressure base of 14.73 psia. Computations of volumes will follow industry
accepted practice.

D.3 Pressure, Temperature. Buyer may measure the atmospheric pressure or may assume the
atmospheric pressure to be 13.2 psia. Buyer may determine the gas temperature by using a recording
thermometer; otherwise, the temperature will be assumed to be 60° F.

D.4 Check Meters. Seller may install, maintain, and operate in accordance with accepted
industry practice at its own expense pressure regulators and check measuring equipment of standard
make using separate taps. Check meters shall not interfere with operation of Buyer’s equipment.
Buyer will have access to Seller’s check measuring equipment at all reasonable hours, but only
Seller will calibrate, adjust, operate, and maintain it.

D.5 Meter Tests. At least semiannually, Buyer will verify the accuracy of Buyer’s
measuring equipment, and Seller or its lease operator will verify the accuracy of any check
measuring equipment. If Seller’s lease operator or Buyer notifies the other that it desires a
special test of any measuring equipment, they will cooperate to secure a prompt verification of the
accuracy of the equipment. If either party at any time observes a variation between the delivery
meter and the check meter, it will promptly notify the other, and both will then cooperate to
secure an immediate verification of the accuracy of the equipment. Buyer will give Seller’s lease
operator reasonable advance notice of the time of all special tests and calibrations of meters and
of sampling for determinations of gas composition and quality, so that the lease operator may have
representatives present to witness tests and sampling or make joint tests and obtain samples with
its own equipment. Seller will give or cause its lease operator to give reasonable advance notice
to Buyer of the time of tests and calibrations of any check meters and of non-routine sampling by
Seller for determination of gas composition and quality. Seller may request sampling and analysis
of Buyer’s measuring equipment more frequently than semi-annually. If Seller so requests, Seller
or its lease operator must be present when the special sample is captured and authorize the test in
writing. If new sample differs materially (i.e. the stated methane or any NGL component’s result
changes by more than 2% from the previous test), Buyer will absorb the cost of the sample and
analysis. If the new sample results do not differ materially from the previous test under the
preceding sentence, Seller will absorb the cost of the sample and analysis.

D.6 Correction of Errors. If at any time any of the measuring or testing equipment is
found out of service or registering inaccurately in any percentage, the measuring party will
adjusted it promptly to read accurately within the limits prescribed by the manufacturer. If any
measuring equipment is found to be inaccurate or out of service by an amount exceeding the greater
of (i) 2.0 percent at a

A-2

 

recording corresponding to the average hourly rate of flow for the period since the last test, or
(ii) 100 Mcf per month, the measuring party will correct previous readings to zero error for any
known or agreed period. Buyer will determine the volume of gas delivered during that period by the
first feasible of the following methods:

(i) Using the data recorded by any check measuring equipment if registering accurately;

(ii) Correcting the error if the percentage of error is ascertainable by calibration, test,
or mathematical calculation; or

(iii) Using deliveries under similar conditions during a period when the equipment was
registering accurately.

No adjustment will be made for inaccuracies unless they exceed the greater of (i) 2.0 percent of
affected volumes, or (ii) 100 Mcf per month.

D.7 Meter Records. The parties will preserve for a period of at least two years all test
data, charts, and similar measurement records. The parties will raise metering questions as soon
as practicable after the time of production. No party will have any obligation to preserve
metering records for more than two years except to the extent that a metering question has been
raised in writing and remains unresolved.

E. DETERMINATION OF GAS COMPOSITION, GRAVITY, AND HEATING VALUE

          At least monthly, Buyer will obtain a representative sample of Seller’s gas delivered at
each Delivery Point; Buyer may use spot sampling, continuous samplers, or on-line chromatography.
By chromatography or other accepted method in the industry, Buyer will determine the composition,
gravity, and gross heating value of the hydrocarbon components of Seller’s gas in Btu per cubic
foot on a dry basis at standard conditions, then adjust the result for the water vapor content of
the gas (by either the volume or Btu content method) using an industry accepted practice. No
adjustment will be made if the water content of the gas is less than seven (7) pounds. No heating
value will be credited for Btus in H2S or other non-hydrocarbon components. Buyer will
make the first determination of Btu content for Seller’s deliveries within a reasonable time after
deliveries of gas begin. If Buyer uses a continuous sampler or on-line chromatography, the
determinations will apply to the gas delivered while the sampler was installed. If not, the
determination will apply until the first Day of the month following the next determination.

F. QUALITY OF GAS

F.1 Quality Specifications. The gas shall be merchantable natural gas, at all times
complying with the following quality requirements. The gas shall be commercially free of crude
oil, water in the liquid phase, brine, air, dust, gums, gum-forming constituents, bacteria, and
other objectionable liquids and solids, and not contain more than:

(a) 1/4 grain of H2S per 100 cubic feet.

(b) Five grains of total sulfur nor more than one grain of mercaptan per 100 cubic feet.

(c) Two mole percent of carbon dioxide.

(d) Three mole percent of nitrogen.

(e) Zero parts per million by volume of oxygen, and not have been subjected to any treatment or
process that permits or causes the admission of oxygen, that dilutes the gas, or otherwise causes
it to fail to meet these quality specifications.

(f) Five mole percent of combined carbon dioxide, nitrogen, and oxygen.

The gas shall:

(g) Not exceed 120°F in temperature at the Delivery Point.

(h) Have a total heating value of at least 1,050 Btus per cubic foot.

(i) If a third party pipeline receiving the gas delivered has more stringent quality specifications
than those stated above, Seller’s gas shall conform to the more stringent pipeline quality
standard.

F.2 Quality Tests. Buyer will make determinations of conformity of the gas with the above
specifications using procedures generally accepted in the gas industry as often as Buyer reasonably
deems necessary. If in the lease operator’s judgment the result of any test or determination is
inaccurate, Buyer upon request will again conduct the questioned test or determination. Seller
will bear the costs of the additional test or determination unless it shows the original test or
determination to have been materially inaccurate.

F.3 Separation Equipment. Seller will employ only conventional mechanical separation
equipment at all production sites covered by this Contract. Low temperature, absorption, and
similar separation facilities are not considered conventional mechanical separation equipment.
Except for liquids removed through operation of conventional mechanical separators and except for
removal of substances as required to enable Seller to comply with this Section F, Seller will
remove no components of the gas prior to delivery to Buyer.

F.4 Rights as to Off Specification Gas. If any of the gas delivered by Seller fails to
meet the quality specifications stated in this Section F, Buyer may at its option accept delivery
of and pay for the gas or discontinue or curtail taking of gas at any Delivery Point whenever its
quality does not conform to the quality specifications. If

A-3

 

Buyer accepts delivery of off specification gas from Seller or incurs costs relating to inferior
gas quality in its gathering system, Buyer will deduct from the proceeds otherwise payable a fee of
$0.05/Mcf plus $0.02 times the total mole percent, and any fraction of a mole percent, of
H2S and CO2 times the Mcf quantity delivered at the affected off quality
Delivery Points. If Buyer rejects delivery, Buyer’s notice to that effect will terminate this
Contract with respect to the off specification gas named in the notice. If Buyer accepts delivery
of gas from Seller that is off specification for nitrogen content, Buyer will deduct a fee of
$0.06/Mcf for each mole percent, and each fraction of a mole percent, of nitrogen content over the
allowed nitrogen specification for all volumes delivered by Seller at the affected excess nitrogen
Delivery Points. As of the beginning of each calendar year beginning with 2011, Buyer will adjust
the current year’s off-specification fees upward or downward, but not below the initial fees, by an
amount equal to the annual percentage change in the preliminary estimate of the implicit price
deflator, seasonally adjusted, for the gross domestic product (“GDP”) as computed and most recently
published by the U.S. Department of Commerce, rounded to the nearest 100th cent, or in
its absence, a similar successor adjustment factor designated by Buyer.

G. BILLING AND PAYMENT

G.1 Statement and Payment Date. Buyer will furnish to Seller on or before the
twenty-fifth (25rd) Day of each month a statement showing the volume of gas and NGLs
delivered by or allocated to Seller during the previous month and Buyer’s calculation of the
amounts due under this Contract for the previous month’s deliveries. Buyer will pay Seller by wire
transfer of immediately available funds on or before the last business Day of each month, for all
gas and NGLs delivered by or allocated to Seller during the preceding month. As between the
parties, late payments by Buyer and recoupments/refunds from Seller will carry simple interest at
the lower of 6% per annum or the maximum lawful interest rate; provided that no interest will
accrue as to monthly principal amounts of less than $1,000 due for less than one year when paid.
The parties waive any rights to differing interest rates. Except as limited in Section G.2 below,
Buyer may recover any uncontested overpayments or collect any uncontested amounts due from Seller
to Buyer under this Contract by deducting them from proceeds payable to Seller.

G.2 Audit Rights; Time Limit to Assert Claims.

(a) Each party will have the right during reasonable business hours to examine the books, records
and charts of the other party to the extent necessary to verify performance of this Contract and
the accuracy of any payment, statement, charge, or computation upon execution of a reasonable
confidentiality agreement. If any audit examination or review of the party’s own records reveals
an inaccuracy in any payment, Buyer will promptly make the appropriate adjustment.

(b) No adjustment for any billing or payment shall be made, and payments shall be final after
the lapse of two years from their due date except as to matters that either party has noted in a
specific written objection to the other party in writing during the two year period, unless
within the two year period Buyer has made the appropriate correction. However, Seller’s
responsibilities for severance taxes and third party liabilities and related interest are not
affected by this subsection.

(c) No party will have a right to recoup or recover prior overpayments or underpayments that
result from errors that occur in spite of good faith performance if the amounts involved do not
exceed $10/month/meter. Either party may require prospective correction of such errors.

G.3 Metering Records Availability. Buyer will not be required to furnish gas volume
records relating to electronic recording devices for gas meters other than daily volume information
unless there are indications the meter was not operating properly.

H. FORCE MAJEURE

H.1 Suspension of Performance. Subject to Section 5.4 (c) of the Contract, if either
party is rendered unable, wholly or in part, by Force Majeure to carry out its obligations under
this Contract, other than to make payments due, the obligations of that party, so far as they are
affected by Force Majeure, will be suspended during the continuance of any inability so caused, but
for no longer period.

H.2 Force Majeure Definition. “Force Majeure” means acts of God, strikes, lockouts or
other industrial disturbances, acts of the public enemy, wars, blockades, insurrections, riots,
epidemics, landslides, lightning, earthquakes, storms, floods, washouts, arrests and restraints of
governments and people, civil disturbances, fires, explosions, breakage or accidents to machinery
or lines of pipe, freezing of wells or lines of pipe, partial or entire failure of wells or sources
of supply of gas, inability to obtain at reasonable cost servitudes, right of way grants, permits,
governmental approvals or licenses, inability to obtain at reasonable cost materials or supplies
for constructing or maintaining facilities, and other causes, whether of the kind listed above or
otherwise, not within the control of the party claiming suspension and which by the exercise of
reasonable diligence the party is unable to prevent or overcome.

H.3 Labor Matters Exception. The settlement of strikes or lockouts will be entirely within
the discretion of the party having the difficulty, and settlement of strikes, lockouts, or other
labor disturbances is not required when the affected party considers it inadvisable.

A-4

 

I. WARRANTY OF TITLE

          Seller warrants that it has good title and processing rights to the gas delivered, free
and clear of any and all liens, encumbrances, and claims, or that Seller has good right and lawful
authority to sell the same. Seller grants to Buyer the right to process Seller’s gas for extraction
of NGLs and other valuable components. If Seller’s title or right to receive any payment is
questioned or involved in litigation, upon notice, Buyer will have the right to withhold the
contested payments without interest until title information is received, during the litigation,
until the title or right to receive the questioned payments is freed from question, or until Seller
furnishes security for repayment acceptable to Buyer. Without impairment of Seller’s warranty of
title to gas and gas processing rights, if Seller owns or controls less than full title to the gas
delivered, Buyer will make payments only in the proportion that Seller’s interest bears to the
entire title to the gas.

J. ROYALTY AND OTHER INTERESTS

          Seller is responsible for all payments to the owners of all working interests, mineral
interests, royalties, overriding royalties, bonus payments, production payments, and the like.
Buyer assumes no liabilities or duties to Seller’s working or mineral interest, royalty, or other
interest owners under this Contract.

K. SEVERANCE AND SIMILAR TAXES

K.1 Included in Price. Reimbursement to Seller for Seller’s full liability for
severance and similar taxes levied upon Seller’s gas production is included in the prices payable
under this Contract, regardless of whether some included interests may be exempt from taxation.

K.2 Tax Responsibilities and Disbursements. Seller shall bear, and unless otherwise
required by law, will pay to taxing authorities all severance, production, excise, sales, gross
receipts, occupation, and other taxes imposed upon Seller with respect to the gas on or prior to
delivery to Buyer. Buyer will bear and pay all taxes imposed upon Buyer with respect to the gas
after delivery to Buyer; however, if Buyer incurs any charge on the carbon or MMBtu content of
Seller’s gas, whether in the form of a “cap and trade” system, tax, or other impost, the parties
shall promptly negotiate in good faith an equitable resolution of the matter, to be effective as of
the initial effective date of the new or additional tax burden.

L. INDEMNIFICATION AND RESPONSIBILITY FOR INJURY OR DAMAGE

L.1 Title, Royalty, and Severance Taxes. SELLER RELEASES AND AGREES TO DEFEND,
INDEMNIFY, AND SAVE BUYER, ITS AFFILIATES, AND THEIR OFFICERS, EMPLOYEES, AND AGENTS HARMLESS FROM
AND AGAINST ALL CLAIMS, CAUSES OF ACTION, LIABILITIES, AND COSTS (INCLUDING REASONABLE ATTORNEYS’
FEES AND COSTS OF INVESTIGATION AND DEFENSE) CAUSED BY ANY BREACH OF SECTIONS I, J, AND K ABOVE.

L.2 Responsibility for Injury or Damage. As between the parties, Seller will be in control
and possession of the gas deliverable hereunder and responsible for any injury or damage relating
to handling or delivery of gas until the gas has been delivered to Buyer at the Delivery Points;
after delivery, Buyer will be deemed to be in exclusive control and possession and responsible for
any injury or damage relating to handling or gathering of gas. THE PARTY HAVING RESPONSIBILITY
UNDER THE PRECEDING SENTENCE SHALL RELEASE, DEFEND, INDEMNIFY, AND HOLD THE OTHER PARTY, ITS
AFFILIATES, AND THEIR OFFICERS, EMPLOYEES, AND AGENTS HARMLESS FROM AND AGAINST ALL CLAIMS, CAUSES
OF ACTION, LIABILITIES, AND COSTS (INCLUDING REASONABLE ATTORNEYS’ FEES AND COSTS OF INVESTIGATION
AND DEFENSE) ARISING FROM ACTUAL AND ALLEGED LOSS OF GAS, PERSONAL INJURY, DEATH, AND DAMAGE FOR
WHICH THE PARTY IS RESPONSIBLE UNDER THIS SECTION; PROVIDED THAT NEITHER PARTY WILL BE INDEMNIFIED
FOR ITS OWN NEGLIGENCE OR THAT OF ITS AGENTS, SERVANTS, EMPLOYEES OR CONTRACTORS.

M. RIGHT OF WAY

          Insofar as Seller’s lease or leases permit and insofar as Seller or its lease operator
may have any rights however derived (whether from an oil and gas lease, easement, governmental
agency order, regulation, statute, or otherwise), Seller grants to Buyer and Buyer’s gas gathering
contractor, if any, and their assignees the right of free entry and the right to lay and maintain
pipelines, meters, and any equipment on the lands or leases subject to this Contract as reasonably
necessary in connection with the purchase or handling of Seller’s gas. Subject to the limitations
above, upon written request from Buyer to Seller, Seller shall grant, in writing, to Buyer or
Buyer’s designee, recordable rights of ingress and egress as necessary or appropriate for the
purposes of complying with the terms of this Contract. All pipelines, meters, and other equipment
placed by Buyer or Buyer’s contractors on the lands and leases will remain the property of the
owner and may be removed by the

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owner at any time consistent with its obligations under this Contract. Without limitation, Buyer
or its gathering contractor may disconnect and remove measurement and other facilities from any
Delivery Point if this Contract is terminated with respect to all production connected upstream of
such Delivery Point.

N. ASSIGNMENT

N.1 Binding on Assignees. Either party may assign this Contract. This Contract is
binding upon and inures to the benefit of the successors, assigns, heirs, personal representatives,
and representatives in bankruptcy of the parties, and, subject to any prior dedications by the
assignee, shall be binding upon any purchaser of Buyer’s Facilities and upon any purchaser of the
properties of Seller subject to this Contract. Nothing contained in this Section will prevent
either party from mortgaging its rights as security for its indebtedness, but security is
subordinate to the parties’ rights and obligations under this Contract.

N.2 Notice of Assignment. Seller will make any assignment or sublease of any oil and gas
properties or any gas rights contracted to Buyer expressly subject to this Contract. No transfer
of or succession to the interest of Seller, however made, will bind Buyer unless and until the
original instrument or other proper proof that the claimant is legally entitled to an interest has
been furnished to Buyer at its Division Order address noted in the Notices Section or subsequent
address.

O. MISCELLANEOUS PROVISIONS

O.1 Governing Law. THIS CONTRACT SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE
WITH THE LAWS OF THE STATE OF TEXAS, without reference to those that might refer to the laws of
another jurisdiction.

O.2 Default and Nonwaiver. A waiver by a party of any one or more defaults by the other in
the performance of any provisions of this Contract will not operate as a waiver of any future
default or defaults, whether of a like or different character.

O.3 Counterparts. This Contract may be executed in any number of counterparts, all of
which will be considered together as one instrument, and this Contract will be binding upon all
parties executing it, whether or not executed by all parties owning an interest in the producing
sources affected by this Contract. Signed copies of this Contract and facsimiles of it shall have
the same force and effect as originals.

O.4 Negotiations; Entire Agreement; Amendment; No Third Party Beneficiaries. The language
of this Contract shall not be construed in favor of or against either party, but shall be construed
as if the language were drafted mutually by both parties. This Contract constitutes the final and
complete agreement between the parties. There are no oral promises, prior agreements,
understandings, obligations, warranties, or representations between the parties relating to this
Contract other than those stated herein. All waivers, modifications, amendments, and changes to
this Contract shall be in writing and signed by the authorized representatives of the parties. The
relations between the parties are those of independent contractors; this Contract creates no joint
venture, partnership, association, other special relationship, nor any fiduciary obligations.
There are no third party beneficiaries of Buyer’s sales contracts or of this Contract.

O.5
Ratification and Third Party Gas. Notwithstanding anything contained herein to
the contrary, Buyer has no duty under this Contract to purchase or handle gas attributable to
production from interests of third parties that has been purchased by Seller for resale, except
that Buyer will purchase Other WI Gas. “Other WI Gas” means gas attributable to working and
mineral interests owned by third parties in wells operated by Seller that are subject to this
Contract that Seller has the right to purchase or market under an operating agreement. If Buyer
requests in writing that Seller obtain ratification of this Contract from owners of Other WI Gas,
Seller will use reasonable commercial efforts to cause those Other WI Gas owners to execute and
deliver to Buyer an instrument prepared by Buyer for the purpose of ratifying and adopting this
Contract with respect to the owner’s Other WI Gas, and the ratifying owner will become a party to
this Contract with like force and effect as though the Other WI owner had executed this Contract as
amended as of the time of the ratification, and the terms of this Contract as then amended will
become binding upon Buyer and the ratifying owner.

O.6 Compliance with Laws and Regulations. This Contract is subject to all valid statutes
and rules and regulations of any duly constituted federal or state authority or regulatory body
having jurisdiction. Neither party will be in default as a result of compliance with laws and
regulations.

O.7 Fees and Costs; Damages. If a breach occurs, the parties are entitled to recover as
their sole and exclusive damages for breach of the price and quantity obligations under this
Contract the price for gas taken by Buyer in the case of Seller and the lost margin less avoided
costs in the case of Buyer. If mediation or arbitration is necessary to resolve a dispute other
than one arising under the indemnification obligations of this Contract, each party agrees to bear
its own attorneys’ fees and costs of investigation and defense, and each party waives any right to
recover those fees and costs from the other party or parties.

O.8 Mutual Waiver of Certain Remedies. Except as to the parties’ indemnification
obligations, NEITHER PARTY SHALL BE LIABLE OR OTHERWISE RESPONSIBLE TO THE OTHER FOR CONSEQUENTIAL
OR INCIDENTAL DAMAGES, FOR LOST PRODUCTION, OR FOR PUNITIVE DAMAGES AS TO ANY ACTION OR OMISSION,
WHETHER CHARACTERIZED AS A CONTRACT BREACH OR TORT, THAT ARISES OUT OF OR RELATES TO THIS

A-6

 

CONTRACT OR ITS PERFORMANCE OR NONPERFORMANCE.

O.9 Dispute Resolution. The parties desire to resolve any disputes that may arise
informally if possible. To that end, if a dispute arises, the party raising the issue will give
written notice of the issue or issues to the other party and each party will appoint a senior
employee or executive to negotiate with the other party concerning the dispute. If the dispute
cannot be so resolved in a reasonable time, the parties may agree to non-binding mediation or
binding arbitration, or either party may file a suit to resolve the matter. Any suit relating in
any way to this Contract must be filed only in the state or federal courts of competent
jurisdiction in Harris, Midland, or Tarrant Counties, Texas, and in no other forum. Each of the
parties (a) irrevocably submits to the exclusive jurisdiction of any court having jurisdiction
sitting in those counties for the purposes of any suit, action, or proceeding arising out of or
relating to this Agreement, and (b) waives, and agrees not to assert in any suit, action, or
proceeding, any claim that: (i) it is not personally subject to the jurisdiction of the courts of
competent jurisdiction in that county or of any other court to which proceedings in those courts
may be appealed; (ii) the suit, action, or proceeding is brought in an inconvenient forum; or that
(iii) the venue of the suit, action, or proceeding is improper.

END OF EXHIBIT A TO

GAS PURCHASE CONTRACT

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EXHIBIT B-1 to GAS PURCHASE CONTRACT between

APPROACH RESOURCES I, LP and APPROACH OIL & GAS INC. as Seller and

DCP MIDSTREAM, LP as Buyer

Dated as of January 1, 2011

COMMITTED AREAS MAP

 

 

 

 

EXHIBIT B-2 to GAS PURCHASE CONTRACT between

APPROACH RESOURCES I, LP and APPROACH OIL & GAS INC. as Seller and

DCP MIDSTREAM, LP as Buyer

Dated as of January 1, 2011

DELIVERY POINTS

CROCKETT AND SCHLEICHER COUNTIES, TEXAS

1. Northeast Ozona Area — Buyer’s Existing Meter No. 76137155 on the Peachridge line or
successor meter in Section 7, Block EF, GC & SF RR Co Survey, Crockett County, Texas.

2. Cinco Terry Area — Buyer’s meter is to be installed on Buyer’s FinTex Line at its East
crossing with Highway 163 in Section 16, Block CD, GC & SF RR Co Survey, Crockett County,
Texas. This Delivery Point is not to be active prior to December 1, 2012, and is subject to
non-exercise of the Preferential Right and to the other provisions stated in Section 1(b) of
this Contract.

3. Block 54 Area — Buyer’s meter is to be installed on University Land acreage, in Section
20, Block 54, Schleicher County, Texas. Seller will construct the line from Section 20 to
Section 36.

All of these locations are at or are to be approximately at the locations shown in the attached
Exhibit B-1 Committed Areas Map.

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