ex10x12.htm

PARTICIPATION AGREEMENT

This Participation Agreement (hereinafter "Agreement") is made and entered into effective November 1, 2013, by and between PetroShare Corp., hereinafter referred to as "PetroShare", and LLOCO L.L.C. ("Participant").

RECITALS:

A. PetroShare has acquired certain oil and gas leases described on. Exhibit "A" and Exhibit "B", attached hereto ("Existing Leases").

B. Participant wishes to participate with PetroShare in the drilling and development of the Leases pursuant to the provisions of this Agreement.

Now therefore, the parties hereto, for the mutual promises contained herein and other good and valuable consideration, the sufficiency of which is hereby acknowledged, do hereby contract and agree as follows:

I. DEFINITIONS

1.	Effective Date: The Effective Date is November 1, 2013.

2.	Existing Leases: The oil and gas leases on Exhibit "A" and "B", attached hereto, which includes the acreage required for the drilling of the Obligation Well.

Obligation Wells: The wells will be drilled from a common well pad on Exhibit A leases, and will be the Kowach #3-25 well, located in NESW Section 25, T6N R90W, a vertical well bore and the Voloshin #3-25 well, located in NESW Section 25, T6N R90W; directional well bore to test the Niobrara formation at approximately, 7855 feet TVD. Upon reaching total depth in the first Obligation Well and upon the completion of mud logging and open hole logging operations, PetroShare will provide such data to all JOA working interest participants along with its well evaluation report. Participant(s) shall have forty eight (48) hours from the receipt of the data to make its election whether to proceed with the drilling of the second Obligation Well. In the event a simple majority of JOA participants elect not to proceed with the drilling of the second Obligation Well, PetroShare shall release the rig and waive the requirement to drill the second Obligation Well.

Operator:

a)	PetroShare Corp or its successor, as to Exhibit A leases only

b)	Quicksilver Resources, Inc. or its successor, as to Exhibit B leases only

5.	Operating Agreement(s):

a)	Sec 25 Operating Agreement: The joint operating agreement, covering lands listed in Exhibit A only and attached hereto as Exhibit "D"

b)	Quicksilver Operating Agreement: The joint operating agreement, covering lands listed in Exhibit B only and attached hereto as Exhibit "E".

Participant Interest: A pro rata Working Interest in the Leases and Obligation Wells of 25.0000%, having a net revenue interest of not less than 19.575% in Exhibit A Leases and a 25.0000% Interest of PetroShare's Net Working Interest having a net revenue interest proportionately reduced to not less than 20.000% of 8/8ths in Exhibit B Leases, as calculated on a weighted average basis.

8.	Working Interest: The cost bearing interest created by oil and gas leases. Working Interest may also refer to the share of ownership attributable to an unleased mineral interest.

9.	Net Revenue Interest: The share of the gross production proceeds.

10.	Project Area: Shall be any area(s) covering the Existing Leases in which there is ongoing operations including but not limited to; leasing, drilling and completion operations; seismic operations, active producing wells.

II. PROSPECT FEE

A. PaymentofProspect Fee.Participant shall pay an aggregate prospect fee to PetroShare upon the execution of this Agreement equal to the sum of $187,500 ("Prospect Fee").

III. DRILLING AND DEVELOPMENT.

A. Obligation Wells. Participant agrees to pay for its Participant Interest share of the drilling, completion and equipping, or the plugging and abandonment, of the Obligation Wells. PetroShare shall use its commercially reasonable efforts to commence the drilling of the first Obligation Well by December l, 2013.

B. Interests Earned. Upon Participant paying the Prospect Fee, together with its share of the costs for the drilling, completion and equipping, or the plugging and abandonment of an Obligation Well(s), Participant shall be assigned an undivided interest in and to the Existing Leases equal to Participant's Interest of PetroShare's interest in the Existing Leases as to the Leases listed on Exhibit A & B attached hereto and as to all depths. All assignments will be subject to all royalties, overriding royalties, production payments, net profits interests and similar burdens existing as of the date hereof.

C. Subsequent Drilling and Development Operations. After drilling and completion of the Obligation Well(s), all subsequent wells ("Subsequent Wells") and subsequent operations shall be proposed in accordance with the applicable Operating Agreement and the provisions of this Agreement, with the Participant being responsible for its Participant Interest, shall be subject to any elections to not participate under such Operating Agreement.

IV. OPERATIONS WITHIN PROJECT AREA

A. Operating Agreement. All operations within the Project Area shall be conducted pursuant to the applicable Operating Agreement governing the Existing Leases, as the case may be, ("Operating Agreement"), reference to which is hereby made for all purposes, except as expressly modified by the terms hereof. In the event of a conflict between this Agreement and the applicable Operating Agreement, this Agreement shall control.

B. Cash Advances. Notwithstanding anything in the Operating Agreement(s) to the contrary, PetroShare shall have the right to require cash advances from Participant with respect to the proposed drilling and completion of one or more Obligation Wells. Such request shall be in the form of one or more Authorities for Expenditure {"AFEs") and payment shall be due within 20 days following receipt of the AFEs. Provided however that such AFE's shall not be issued by PetroShare more than 30 days in advance of the confirmed spud date (i.e. drilling commencement date) of the applicable Obligation Well(s).

V. PROPORTIONATE REDUCTION

A. Proportionate Reduction Clause: Ifan oil and gas lease or other Mineral Interest covers less than the entire mineral fee estate, or if a party's interest in the applicable lease or Mineral Interest is less than a 100% ownership interest, any interest conveyed or reserved pursuant to this Agreement is intended to be proportionately reduced to accord to (i) the proportion of mineral interest covered by the relevant oil and gas lease or other Mineral Interest, and (ii) the proportion of ownership held by the conveying party, in the case of a conveyance, or the burdened party, in the case of a reservation of interest. However, such proportionate reduction shall not reduce Participant's Working Interest or Net Revenue Interest in the Existing Leases as a whole.

VI. CONFIDENTIALITY

A. Confidentiality. The parties acknowledge that the information that is the subject matter of this Agreement (including but not limited to all well information acquired by operations conducted under the Operating Agreement(s)) is sensitive and confidential proprietary information belonging to the parties. Each party, for itself and its Affiliates, agrees not to release or disclose or otherwise make the information available to or to furnish any of said information to any third party without (i) obtaining the agreement of the third party to maintain such information confidential and to not use such information other than in connection with investing in or participating with or purchasing interests from the disclosing party, or (ii) first obtaining the express written consent of the other party. Any such release or disclosure if approved shall be conditioned upon the third party expressly agreeing to all terms herein and becoming a party to and subject to a Confidentiality Agreement. Nothing contained above shall restrict or impair any party's right to use or disclose any of the information which is: (1) at the time of disclosure available to the public through no act or omission of that party; (2) can be shown was lawfully in that party's possession prior to the time of this Agreement; or (3) is independently made available to that party by a third party who is independently entitled to disclose such information and that party shows that the right of such third party to disclosure existed prior to the date of this Agreement. Also, nothing contained above shall restrict Participant from providing production results to its investors or lending institutions for the purposes of financing.

B. Public Disclosure. Subject to the exceptions set forth below, and unless otherwise agreed upon by the parties, the parties intend to keep material information concerning the entering into of this Agreement and the location of the Project Area confidential to the extent any disclosure thereof could impair the ongoing activities of the parties. Notwithstanding such intent, either party may make any public disclosure to the extent that, upon advice of such party's counsel, such disclosure is advisable to comply with United States or state securities laws, rules or regulations. Any proposed press release or other disclosure, shall be provided to the other party in advance on a confidential basis for its information and comment.

VII. TAX ELECTION

This Agreement is not intended to create, and shall not be construed to create, a relationship of partnership or an association for profit between or among the parties hereto except as provided herein. Each party hereby affected elects to be excluded from the application of all the provisions of Subchapter "K", Chapter 1, Subtitle "A", of the Internal Revenue Code of 1986 and all amendments thereto.

VIII. PAYMENT OF DELAY RENTALS AND LEASE EXTENSIONS

Operator shall be responsible for making any payment of delay rentals, shut in royalties and minimum royalty payments on the Leases. Participant shall bear and pay its share of such payments. Participant shall be billed and shall pay for said costs in the manner set forth for the billing and paying of direct costs in the COPAS accounting procedures attached to the applicable Operating Agreement. Operator shall not be liable to Participant for any loss resulting from a good faith effort to properly do so.

IX. NO JOINT LIABILITY

The rights, duties, obligations and liabilities of the parties hereto shall be several and not joint or collective. Each party hereto shall be responsible only for its obligations as herein set out and shall be liable only for its share of the cost and expense as herein provided; it being the express purpose and intention of the parties that their interest in this Agreement and the rights and property acquired in connection herewith shall be held by them as tenants in common. Except for the tax election which the parties may have made, it is not the purpose or intention of this Agreement to create any mining partnership, commercial partnership or other partnership.

X. ASSIGNMENTS OF LEASES

Any assignment of any interest pursuant to this Agreement by and between the parties hereto shall be made with a special warranty of title by through and under the assignor, but not otherwise and on the form attached hereto as Exhibit "C" which shall be for recording in the official records of the county in which the Lease lies. Where applicable, separate assignments of operating rights shall likewise be made on such State and Federal forms as required by rule or regulation. Any assignment hereafter executed shall specifically refer to, and be made subject to, the terms and conditions hereof, and shall convey a working interest equal to the Participant Interest.

XI. FORCE MAJEURE

Should any party be prevented or hindered from complying with any obligation created hereunder, other than the obligation to pay money, by reason of fire, flood, storm, act of God, governmental authority, governmental action or inaction, failure or delay in obtaining any necessary permits, labor disputes, war, the inability to secure qualified labor, geoscience data, title abstracts, curative title work, lease brokers, entry onto the land, drilling equipment and drilling rig(s) at prevailing market rates, drilling tools, materials or transportation, or any other cause not enumerated herein but which is beyond the normal control of the party whose performance is affected, then the performance of any such obligation shall be suspended during the period of such prevention or hindrance, provided the affected party promptly notifies the other party of such force majeure circumstances and exercises all reasonable diligence to remove the cause of force majeure.

XII. EXHIBITS

The following exhibits are attached to this Agreement:

Exhibit "A" - Sec 25 Leases

Exhibit "B" - Quicksilver Leases

Exhibit "C" - Form of Assignment

Exhibit "D" - Sec 25 Operating Agreement

Exhibit "E" - Quicksilver Operating Agreement

If the terms of any of these Exhibits conflict with the terms of this Agreement, this Agreement shall control.

XIII. MISCELLANEOUS

A. Assignment: Participant may assign its interest under this Agreement provided that Participant remains liable for or guarantees the performance of its assignee and provided Participant gives PetroShare appropriate documentation evidencing such assignment.

B. Governing Law: This Agreement and other instruments executed in accordance with it, except for assignments of lands, or the execution hereof shall be governed by and interpreted according to the laws of the State of Colorado. Forum and venue shall be exclusively in Denver, Colorado. As to assignments of lands, they shall be governed by the laws of the State wherein they lie.

C. Entire Agreement: This Agreement, the documents to be executed hereunder, and the Exhibits attached hereto constitute the entire agreement between the parties, supersedes all prior agreements, understandings, negotiations and discussions, whether oral or written, of the parties, and there are no warranties, representations or other agreements

D. Waiver: No waiver of any of the provisions of the Agreement shall be deemed or shall constitute a waiver of any other provisions hereof (whether or not similar), nor shall such waiver constitute a continuing waiver unless otherwise expressly provided.

E. Captions; Definition of "Including": The captions in this Agreement are for convenience only and shall not be considered a part of or affect the construction or interpretation of any provision of this Agreement. The term "including or "includes", as used herein, shall mean "including, without limitation," and "includes, without limitation".

F. Binding: This Agreement shall be binding upon and inure to the benefit of the parties hereto and their respective permitted successors, assigns and legal representatives.

G. Notices: Any notice hereunder shall be given in writing by mail, courier, personally, E mail or by facsimile and shall be effective when delivered to the party intended to be notified. The contact information for each party is as follows:

If to PetroSbare:

PetroShare Corp.

7200 So. Alton Way, Ste B220

Centennial , CO 80112

Attn: Frederick J. Witsell

(303) 500-1168 Office

(303) 770-6885 fax

(303) 881-2157 cell

fwitsell@petrosharecoro.com

If to Participant:

LLOCO, L.L.C.

1001 Ochsner Blvd., Ste 200

Covington, LA 70433

Attn: Judy Reimel

(965) 801-4348

JudyR@LLOG.com

Any party may change their foregoing contact information by notice to the other party.

H. Expenses: Except as otherwise provided herein, each party shall be solely responsible for all expenses incurred by it in connection with this transaction (including fees and expenses of its own counsel and accountants).

I. Execution: This Agreement may be executed in multiple original counterparts, all of which shall together constitute a single agreement and each of which, when executed, shall be binding for all purposes thereof on the executed party, its successors and assigns.

J. Severability: If any term or other provision of this Agreement is invalid, illegal or incapable of being enforced by any rule of law, all other conditions and provisions of this Agreement shall nevertheless remain in full force and effect so long as the economic or legal substance of the transactions contemplated hereby is not affected in any materially adverse manner to either party.

K. Arbitration: Any dispute arising under this Agreement ("Arbitrable Dispute") shall be referred to and resolved by binding arbitration in Denver, Colorado, to be administered by and in accordance with the Commercial Arbitration Rules of the American Arbitration Association. Arbitration shall be initiated within the applicable time limits set forth in this Agreement and not thereafter or if no time limit is given, within the time period allowed by the applicable statute of limitations, by one party ("Claimant") giving written notice to the other party ("Respondent") and to the Denver Regional Office of the American Arbitration Association ("AAA"), that the Claimant elects to refer the Arbitrable Dispute to arbitration. All arbitrators must be neutral parties who have never been officers, directors or employees of the parties or any of their Affiliates, must have not less than ten (10) years' experience in the oil and gas industry, and must have a formal financial/accounting, engineering or legal education. The hearing shall be commenced within thirty (30) days after the selection of the arbitrator. The parties and the arbitrators shall proceed diligently and in good faith in order that the arbitral award shall be made as promptly as possible. The interpretation, construction and effect of this Agreement shall be governed by the Laws of Colorado, and to the maximum extent allowed by law, in all arbitration proceedings the Laws of Colorado shall be applied, without regard to any conflicts of laws principles. All statutes of limitation and of repose that would otherwise be applicable shall apply to any arbitration proceeding. The tribunal shall not have the authority to grant or award indirect or consequential damages, punitive damages or exemplary damages.

L. Further Assurances: During the time in which this Agreement is in effect, the parties shall, at any time and from time to time, and without further consideration, execute and deliver or use reasonable efforts to cause to be executed and delivered such other instruments of conveyance and contract, and to take such other actions as either party may reasonably may request effect the intent of this Agreement.

M. Not to be Construed Against Drafter: The parties acknowledge that they have had an adequate opportunity to review each and every provision contained in this Agreement, that they have participated equally in the drafting hereof and that they have had adequate time to submit same to legal counsel for review and comment. Based on said review and consultation, the parties agree with each and every term contained in this Agreement. Based on the foregoing, the parties agree that the rule of construction that a contract be construed against the drafter, if any, shall not be applied in the interpretation and construction of this Agreement.

N. LawsandRegulations:Any reference to any federal, state, local, or foreign statute or law willbe deemed also to refer to all rules and regulations promulgated thereunder, unless the context otherwise requires.

O. Third-Party Beneficiaries: This Agreement is not intended to confer any rights or remedies upon any Person other than the parties and their respective successors and permitted assigns.

P. Investment Representations: Participant understands that the interests evidenced by this Agreement have not been registered under the Securities Act of 1933, the Colorado Securities Act or any other state securities laws (the "Securities Acts").

IN WITNESS WHEREOF, this Agreement is executed effective as of the date hereinabove provided.

Parties:

PETROSHARE CORP		LLOCO, L.L.C.
By:	/s/ Stephen J. Foley	By:	/s/ Kemberlia Ducote
Name:	Stephen J. Foley	Name:	Kemberlia Ducote
Title:	CEO	Title:	Secretary

EXHIBIT A

Buck Peak Participation Agreement Leases dated November 1, 2013


BUCK PEAK LEASES AND EXPIRATION DATES									NET ACRES
LESSOR NAME AND ADDRESS	DESCRIPTION	DATE AND TERM			GROSS ACRES		NET ACRES		CONVEYED	NET REVENUE INTEREST			RECORDING
									10.00%	to be delivered 8/8ths
West Half of Section 25

Jim F. Kowach	T6N-R90W, 6th P.M. Sec 25: W/2	10/31/2008 - 2014 6 years				335.54		167.77	16.78		78.5000	%		20104936

Barbara Wilaby	T6N-R90W, 6th P.M. Sec 25: W/2	10/31/2011 - 2014 3 years				335.54		167.77	16.78		78.5000	%		20103288
Sub Total - Kowach / Wilaby	W/2 Section 25, T6N R90W		100.00	%		335.54		335.54	33.55		78.5000	%

East Half of Section 25
Mark A Voloshin, PO Box 981, Craig, CO 81626	T6N-R90W, 6th P.M. Assessor's Tract # 74 Sec 25: Lots 1, 2, 7, 8, 9,10,15,16	5/12/2011- 2016 Five (5) Years				335.61		52.83	5.28		78.5000	%		20103153

Betty Arnone, 1713 South Vancouver Ct, Lakewood, CO 80228	T6N-R90W, 6th P.M. Assessor's Tract # 74 Sec 25: Lots 1,2,7,8,9,10,15 & 16	5/12/2011- 2016 Five (5) Years				335.61		26.41	2.64		78.5000	%		20102832

Helen McKee, 10436 Jacob Place, Littleton, CO 80125-8932	T6N-R90W, 6th P.M. Assessor's Tract # 74 Sec 25: Lots 1, 2, 7, 8, 9, 10, 15 & 16	5/12/2011- 2016 Five (5) Years				335.61		26.41	2.64		78.5000	%		20102839

Gary R Semro and Robert W. Semro, 6522 Trailhead Rd, Highlands Ranch, CO 80130	T6N-R90W, 6th P.M. Assessor's Tract # 74 Sec 25: Lots 1, 2, 7, 8, 9, 10, 15 & 16	5/12/2011- 2016 Five (5) Years				335.61		26.41	2.64		78.5000	%		20102847

Sharon Fitzgerald (Hebenstreit), 337 Coronado Drive, Sedalia, CO 80135	T6N-R90W, 6th P.M. Assessor's Tract # 74 Sec 25: Lots 1, 2, 7, 8, 9,10,15,16	5/12/2011- 2016 Five (5) Years				335.61		26.41	2.64		78.5000	%		20103140

Brad Ocker (Eugena Grace Voloshin), 9591 County Rd 33, Craig, CO 81625	T6N-R90W, 6th P.M. Assessor's Tract # 74 Sec 25: Lots 1, 2, 7, 8, 9,10,15,16	5/12/2011- 2016 Five (5) Years				335.61		8.55	0.86		78.5000	%		20102856
Sub Total - Semro / Voloshin	E/2 Section 25, T6N R90W		49.7661	%		335.61		167.02	16.702		78.5000	%

BCK LLC Charles S Keith	T6N-R90W, 6th P.M. A ssessor's Tract # 74 Sec 25: Lots 1, 2, 7, 8, 9,10,15,16	2/22/2011 - 2014 3 years + 2 yr ext				335.61		41.43	4.14		77.5000	%		20111728

Strontia springs Resources, LLC James Keith	T6N-R90W, 6th P.M. Assessor's Tract # 74 Sec 25: Lots 1, 2, 7, 8, 9,10,15,16	2/22/2011 - 2014 3 years + 2 yr ext				335.61		41.43	4.14		77.5000	%		20111730

JZTZ LLC Debra Ann Ziehm	T6N-R90W, 6th P.M. Assessor's Tract # 74 Sec 25: Lots 1, 2, 7, 8, 9,10,15,16	2/22/2011 - 2014 3 years + 2 yr ext				335.61		41.43	4.14		77.5000	%		20111729

MKRESOURCES LLC Margaret Keith	T6N-R90W, 6th P.M. Assessor's Tract # 74 Sec 25: Lots 1, 2, 7, 8, 9,10,15,16	2/22/2011 - 2014 3 years + 2 yr ext				335.61		26.41	2.64		77.5000	%		20111731
Sub Total - Keith	E/2 Section 25, T6N R90W		44.9075	%		335.61		150.71	15.07		77.5000	%

Quicksilver Resources Joanie Voloshin	T6N-R90W, 6th P.M. Assessor's Tract # 74 Sec 25: Lots 1,2,7,8,9,10,15,16		2/22/2011 - 2014 3 years + 2 yr ext			335.61		8.94	0.89		82.500	%		20111728

SWEPI thru Quicksilver Resources Joanie Voloshin	T6N-R90W, 6th P.M. Assessor's Tract # 74 Sec 25: Lots 1,2,7,8,9,10,15,16		2/22/2011 - 2014 3 years + 2 yr ext			335.61		8.94	0.89		81.000	%		20111728

		Ownership %			Gross Acres		Net Acres			NRI% Delivered
West Half of Section 25			100.000	%		335.54		335.54	33.55		78.5000	%
East Half of Section 25			100.000	%		335.61		335.61	33.56		78.2247	%
SECTION 25 TOTAL			100.000	%		671.15		671.15	67.12		78.3623	%

EXHIBIT B - Lease Schedule

LLOCO Participation Agreement effective November 1, 2013



LESSOR	LESSEE	DESCRIPTION	EFFECTIVE DATE	EXPIRATION DATE	GROSS ACRES	NET LEASE ACRES	PETROSHARE NET ACRES	NET ACRES CONVEYED	NET REVENUE INTEREST	RECORDING
							7.50%	1.88%	to be delivered 8/8ths
Richard J. Colby	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 21: Lots 11,14,15 & 16 Sec 22: Lots 12 & 13 Sec 27: Lots 3 & 4 Sec 28: Lot 1	11/20/2010	11/19/2015 5 yr lease, 3 yr ext (2018)	369.39	15.40	1.16	0.29	80.00%	20103284
David Colby	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 21: Lots 11,14,15 & 16 Sec 22: Lots 12 & 13 Sec 27: Lots 3 & 4 Sec 28: Lot 1	11/20/2010	11/19/2015 5 yr lease, 3 yr ext (2013)	369.39	15.40	1.16	0.29	80.00%	20103286
Douglas Van Tassel, Diana Lynn Hamilton, Donna Lee Sweet, DeLaine Brown and Debbie Lou Van Tassel, PO Box 335, Craig, CO 81626-0335	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 35: Lots 4 & 5 Sec 34: Lots 1,7,8,9,10,11,12,13,14,15,16	1/10/2011	1/09/2014 3 yr lease, 3 yr ext (2017)	534.62	89.10	6.68	1.67	80.00%	20103146
Florence Van Tassel	Laramie & Associates	T6N-R90W, 6th P.M. Sec 35: Lots 4 & 5 Sec 34: Lots 1,7,8,9,10,11,12,13,14,15,16	1/10/2011	1/09/2016 5 yr lease, 3 yr ext (2019)	534.62	89.10	6.68	1.67	80.00%	20103022
	Buck Peak, LLC (Lease not subjuect to 2010 Quicksilver sale)	T6N-R90W, 6th P.M. Sec 35: Lots 4 & 5 Sec 34: Lots 1,7,8,9,10,11,12,13,14,15,16	1/19/2012	1/19/2015 3 years plus 2 year option	534.62	89.10	89.10	22.28	80.00%	20120379
Gregory J. Knez, Trustee of the Raymond M. & Hellen M. Knez Family Trust	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 19: Lots 5, 6, 11 & 12 Sec 20: N2 less tract (see lease)	3/21/2011	3/20/2016 5 yr lease, 3 yr ext (2019)	270.31	271.07	20.33	5.08	80.00%	20103026
Gregory J. Knez, Trustee of the Raymond M. & Hellen M. Knez Family Trust	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 20: A tract in E 55 acres of E2NEN2 (see lease)	3/21/2011	3/20/2016 5 yr lease, 3 yr ext (2019)	11.45	11.45	0.86	0.21	80.00%	20103024
Marlene Henderson	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 21: Lots 11,14,15 & 16 Sec 22: Lots 12 & 13 Sec 27: Lots 3 & 4 Sec 28: Lot 1	3/30/2011	3/29/2016 5 yr lease, 3 yr ext (2019)	369.39	15.40	1.15	0.29	80.00%	20102819
Barbara Martin	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 21: Lots 11,14,15 & 16 Sec 22: Lots 12 & 13 Sec 27: Lots 3 & 4 Sec 28: Lot 1	3/30/2011	3/29/2016 5 yr lease, 3 yr ext (2019)	369.39	15.40	1.16	0.29	80.00%	20102820
Edward Rutherford	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 21: Lots 11,14,15 & 16 Sec 22: Lots 12 & 13 Sec 27: Lots 3 & 4 Sec 28: Lot 1	3/30/2011	3/29/2016 5 yr lease, 3 yr ext (2019)	369.39	15.40	1.16	0.29	80.00%	20102821

Larry Rutherford	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 21: Lots 11,14,15 & 16 Sec 22: Lots 12 & 13 Sec 27: Lots 3 & 4 Sec 28: Lot 1	3/30/2011	3/29/2016 5 yr lease, 3 yr ext (2019)	369.39	15.40	1.15	0.29	80.00%	20102822
Mark A Voloshin	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 2: Lots 7, 8, 9, 10 less tract (see lease) Sec 2: 15,16,17,18	5/12/2011	5/11/2016 5 yr lease, no ext	333.57	15.41	1.16	0.29	80.00%	20103150
Mark A Voloshin	Buck Peak, LLC	T6N-R90W, 6th P.M. Assesor's Tract # 69 Sec 21: Lots 3, 6, 7 & 10	5/12/2011	5/11/2016 5 yr lease, no ext	164.88	47.11	3.53	0.88	80.00%	20103151
Mark A Voloshin	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 70 Sec 21: Lots 4 & 5	5/12/2011	5/11/2016 5 yr lease, no ext	82.44	24.43	1.83	0.46	80.00%	20103152
Mark A Voloshin	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessors Tract # 83 Sec 27: Lots 5,6,10,11,12,14,15,16 Sec 34: Lots 2,3 less the acreage in Sec 35 and the additional lands in Sec 34	5/12/2011	5/11/2016 5 yr lease, 2 yr ext (2018)	409.65	100.52	7.54	1.88	80.00%	20103155
Mark A Voloshin	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 105 Sec 21: Lots 1,2,8 & 9	5/12/2011	5/11/2016 5 yr lease, 2 yr ext (2018)	164.97	80.96	6.07	1.52	80.00%	20103156
Mark A Voloshin	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessors Tract #82 Sec 26: Lots 4,5,6,11,12,13 & 14 Sec 27:Lots 1,2,5,6,7,8,9,10,11,12,14,15,16	5/12/2011	5/11/2016 5 yr lease, no ext	330.85	162.36	12.18	3.04	80.00%	20103154
Betty Arnone	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 2: Lots 7,8,9,10 Less Tract (see lease) Sec 2: 15,16,17 & 18	5/12/2011	5/11/2016 5 yr lease, 2 yr ext (2018)	333.57	11.56	0.87	0.22	80.00%	20102829
Betty Arnone	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 69 Sec 21: Lots 3, 6, 7, & 10	5/12/2011	5/11/2016 5 yr lease, no ext	164.88	17.59	1.32	0.33	80.00%	20102830
Betty Arnone	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 70 Sec 21: Lots 4 & 5	5/12/2011	5/11/2016 5 yr lease, no ext	82.44	9.16	0.69	0.17	80.00%	20102831


Betty Arnone	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 82 Sec 26: Lots 11, 12, 13, 14 Sec 27: Lots 2, 7, 8, 9	5/12/2011	5/11/2016 5 yr lease, no ext	330.85	26.04	1.95	0.49	80.00%	20102833
Betty Arnone	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 83 Sec 27: Lots 5,6,10,11,12,14,15,16 Sec 34: Lots 2,3 Less acreage (see lease)	5/12/2011	5/11/2016 5 yr lease, no ext	409.65	16.12	1.21	0.30	80.00%	20102834
Betty Arnone	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 105 Sec 21: Lots 1, 2, 8 & 9	5/12/2011	5/11/2016 5 yr lease, no ext	164.97	12.98	0.97	0.24	80.00%	20102835
Betty Jo Lott & Michelle K. McKee	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 2: Lots 7,8,9,10 less tract (see lease) Sec 2: 15,16,17,18	5/12/2011	5/11/2016 5 yr lease, no ext	333.57	11.56	0.87	0.22	80.00%	20102836
Betty Jo Lott & Michelle K. McKee	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 69 Sec 21: Lots 3, 6, 7, & 10	5/12/2011	5/11/2016 5 yr lease, no ext	164.88	17.6	1.32	0.33	80.00%	20102837
Betty Jo Lott & Michelle K. McKee	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 70 Sec 21: Lots 4 & 5	5/12/2011	5/11/2016 5 yr lease, no ext	82.44	9.16	0.69	0.17	80.00%	20102838
Betty Jo Lott & Michelle K. McKee	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 82 Sec 26: Lots 11, 12, 13, & 14 Sec 27: Lots 2, 7, 8 & 9	5/12/2011	5/11/2016 5 yr lease, no ext	330.85	26.04	1.95	0.49	80.00%	20102840
Betty Jo Lott & Michelle K. McKee	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 83 Sec 27: Lots 5, 6, 10, 11, 12, 14, 15 & 16 Sec 34: Lots 2, 3 Less acreage (see lease)	5/12/2011	5/11/2016 5 yr lease, no ext	409.65	16.12	1.21	0.30	80.00%	20102841
Betty Jo Lott & Michelle K. McKee	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 105 Sec 21: Lots 1, 2, 8 & 9	5/12/2011	5/11/2016 5 yr lease, no ext	164.97	12.98	0.97	0.24	80.00%	20102842
Gary R Semro and Robert W. Semro, 6522 Trailhead Rd, Highlands Ranch, CO 80130	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 69 Sec 21: Lots 3, 6, 7, & 10	5/12/2011	5/11/2016 5 yr lease, no ext	164.88	17.59	1.32	0.33	80.00%	20102845
Gary R Semro and Robert W. Semro	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 70 Sec 21: Lots 4 & 5	5/12/2011	5/11/2016 5 yr lease, no ext	82.44	9.16	0.69	0.17	80.00%	20102846


Gary R Semro and Robert W. Semro	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 82 Sec 26: Lots 11, 12, 13, & 14 Sec 27: Lots 2, 7, 8 & 9	5/12/2011	5/11/2016 5 yr lease, no ext	330.85	26.04	1.95	0.49	80.00%	20102848
Gary R Semro and Robert W. Semro	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 83 Sec 27: Lots 5, 6, 10, 11, 12, 14, 15 & 16 Sec 34: Lots 2, 3 Less acreage (see lease)	5/12/2011	5/11/2016 5 yr lease, no ext	409.65	16.12	1.21	0.30	80.00%	20102849
Gary R Semro and Robert W. Semro	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 105 Sec 21: Lots 1, 2, 8 & 9	5/12/2011	5/11/2016 5 yr lease, no ext	164.97	12.98	0.97	0.24	80.00%	20102844
Gary R Semro and Robert W. Semro	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 2: Lots 7,8,9,10 Less Tract (see lease) Sec 2: 15,16,17 & 18	5/12/2011	5/11/2016 5 yr lease, no ext	333.57	11.56	0.87	0.22	80.00%	20102843
Sharon A. Fitzgerald	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 2: Lots 7, 8, 9, 10 less tract (see lease) Sec 2: 15,16,17,18	5/12/2011	5/11/2016 5 yr lease, no ext	333.57	11.56	0.87	0.22	80.00%	20103144
Sharon A. Fitzgerald	Buck Peak, LLC	T6N-R90W, 6th P.M. Assesor's Tract # 69 Sec 21: Lots 3, 6, 7 & 10	5/12/2011	5/11/2016 5 yr lease, no ext	164.88	17.59	1.32	0.33	80.00%	20103138
Sharon A. Fitzgerald	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 70 Sec 21: Lots 4 & 5	5/12/2011	5/11/2016 5 yr lease, no ext	82.44	9.16	0.69	0.17	80.00%	20103139
Sharon A. Fitzgerald	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 82 Sec 26: Lots 11, 12, 13, & 14 Sec 27: Lots 2, 7, 8 & 9	5/12/2011	5/11/2016 5 yr lease, no ext	330.85	26.04	1.95	0.49	80.00%	20103141
Sharon A. Fitzgerald	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessors Tract # 83 Sec 27: Lots 5,6,10,11,12,14,15,16 Sec 34: Lots 2,3 less acreage Sec 35, (see lease)	5/12/2011	5/11/2016 5 yr lease, no ext	409.65	16.12	1.21	0.30	80.00%	20103142
Sharon A. Fitzgerald	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 105 Sec 21: Lots 1,2,8 & 9	5/12/2011	5/11/2016 5 yr lease, no ext	164.97	12.98	0.97	0.24	80.00%	20103143

Eugena Grace Voloshin	Buck Peak, LLC	T6N-R103W, 6th P.M. Sec 31: Lots 7,8,9, NESW, SE T6N-R90W, 6th P.M. Sec 14: Lots 3, 4, 6 T6N-R91W, 6th P.M. Sec 9: Lots 8, 9, 16 Sec 10: Lots 4, 5 T6N-R92W, 6th P.M. Sec 13: SW T6N-R93W, 6th P.M. Sec 13: S2N2, N2S2 T6N-R94W, 6th P.M. Sec 12: E2SE T6N-R99W, 6th P.M. Sec 27: SWSE, SESW Sec 34: NENW	5/12/2011	5/11/2016 5 yr lease, no ext	1320.3	18.748	1.41	0.35	80.00%	20102850
Eugena Grace Voloshin	Buck Peak, LLC	T10N-R90W, 6th P.M. Sec 19: Lot 18 Sec 30: Lots 6 & 8	5/12/2011	5/11/2016 5 yr lease, no ext	117.16	1.663	0.12	0.03	80.00%	20102851
Eugena Grace Voloshin	Buck Peak, LLC	T3N-R91W, 6th P.M. Sec 8: Lots 9 & 16 Sec 9: SW/4SW/4 Sec 16: NW/4, NE/4SW/4	5/12/2011	5/11/2016 5 yr lease, no ext	323.43	4.593	0.34	0.09	80.00%	20102852
Eugena Grace Voloshin	Buck Peak, LLC	T4N-R91W, 6th P.M. Sec 10: Tract in SESW (0.42 acres) T4N-R92W, 6th P.M. Sec 7: Lots 9 & 10 Sec 8: Lots 5, 9, 10, 11, 12, 13, 14 Sec 17: Lot 2 T4N-R101W, 6th P.M. Sec 14: W2NE, NW, N2SW T4N-R102W, 6th P.M. Sec 27: SE Sec 34: NE	5/12/2011	5/11/2016 5 yr lease, no ext	799.7	11.356	0.85	0.21	80.00%	20102853
Eugena Grace Voloshin	Buck Peak, LLC	T5N-R94W, 6th P.M. Sec 7: S2SE Sec 8: SW Sec 17: N2NW Sec 18: NENE T5N-R94W, 6th P.M. Sec 9: SWNE, NWSE, S2SE T5N-R97W, 6th P.M. Sec 3: N2SE, SWSE, E2SW Sec 10: N2NE, NENW	5/12/2011	5/11/2016 5 yr lease, no ext	840	11.93	0.89	0.22	80.00%	20102854
Eugena Grace Voloshin	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 2: Lots 7, 8, 9, 10 less tract (see lease) Sec 2: 15,16,17,18	5/12/2011	5/11/2016 5 yr lease, no ext	333.57	71.30	5.35	1.34	80.00%	20102855
Eugena Grace Voloshin	Buck Peak, LLC	T6N-R90W, 6th P.M. A ssesor's Tract # 69 Sec 21: Lots 3, 6, 7 & 10	5/12/2011	5/11/2016 5 yr lease, no ext	164.88	0.73	0.05	0.01	80.00%	20102857
Eugena Grace Voloshin	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 105 Sec 21: Lots 1,2,8 & 9	5/12/2011	5/11/2016 5 yr lease, no ext	164.97	0.76	0.06	0.01	80.00%	20102858
Eugena Grace Voloshin	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 83 Sec 27: Lots 5, 6, 10, 11, 12, 14, 15 & 16 Sec 34: Lots 2, 3 Less acreage (see lease)	5/12/2011	5/11/2016 5 yr lease, no ext	409.65	0.95	0.07	0.02	80.00%	20102859
Eugena Grace Voloshin	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 82 Sec 26: Lots 11, 12, 13, & 14 Sec 27: Lots 2, 7, 8 & 9	5/12/2011	5/11/2016 5 yr lease, no ext	330.85	1.53	0.11	0.03	80.00%	20102860
Eugena Grace Voloshin	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 70 Sec 21: Lots 4 & 5	5/12/2011	5/11/2016 5 yr lease, no ext	82.44	0.38	0.03	0.01	80.00%	20102861

R. Kirk Lyons	Buck Peak, LLC	T5N-R89W, 6th P.M. Sec 6: Lots 3, 5 SE4NW4 T6N-R89W, 6th P.M. Sec 29: Lot 13 Sec 31: Lot 3,5,6,11 SW4NE4, NW4SE4, NE4SW4, SE4SW4 Sec 32: Lot 4	6/1/2011	5/31/2014 3 yr lease, 2 yr ext (2016)	425.23	47.24	3.54	0.89	80.00%	701711
Ralph C. Lyons & Anna M. Lyons	Buck Peak, LLC	T5N-R89W, 6th P.M. Sec 6: Lots 3, 5 SE4NW4 T6N-R89W, 6th P.M. Sec 29: Lot 13 Sec 31: Lot 3,5,6,11 SW4NE4, NW4SE4, NE4SW4, SE4SW4 Sec 32: Lot 4	6/1/2011	5/31/2014 3 yr lease, 2 yr ext (2016)	425.23	141.74	10.63	2.66	80.00%	701713
Leora L. Smith	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 12: Lots 5,6,8,9,10,13,14,15 Sec 24: Lots 1,2,7,8,9,10,14,15,16	6/1/2011	5/31/2014 3 yr lease, 2 yr ext (2016)	673.54	154.304	11.57	2.89	80.00%	20102588
R. Kirk Lyons	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 12: Lots 5,6,8,9,10,13,14,15 Sec 24: Lots 1,2,7,8,9,10,14,15,16	6/1/2011	5/31/2014 3 yr lease, 2 yr ext (2016)	673.54	51.43	3.86	0.96	80.00%	20102589
Ralph C. Lyons & Anna M. Lyons	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 12: Lots 5,6,8,9,10,13,14,15 Sec 24: Lots 1,2,7,8,9,10,14,15,16	6/1/2011	5/31/2014 3 yr lease, 2 yr ext (2016)	673.54	154.30	11.57	2.89	80.00%	20102587
Mark E. Lyons	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 12: Lots 5,6,8,9,10,13,14,15 Sec 24: Lots 1,2,7,8,9,10,14,15,16	6/1/2011	5/31/2014 3 yr lease, 2 yr ext (2016)	673.54	51.43	3.86	0.96	80.00%	20102586
Terri Lee Smedra	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 12: Lots 5,6,8,9,10,13,14,15 Sec 24: Lots 1,2,7,8,9,10,14,15,16	6/1/2011	5/31/2014 3 yr lease, 2 yr ext (2016)	673.54	51.43	3.86	0.96	80.00%	20102585
Leora L. Smith	Buck Peak, LLC	T5N-R89W, 6th P.M. Sec 6: Lots 3, 5 SE4NW4 T6N-R89W, 6th P.M. Sec 29: Lot 3 Sec 31: Lot 3,5,6,11 SW4NE4,NW4SE4, NE4SW4, SE4SW4 Sec 32: Lot 4	6/1/2011	5/31/2014 3 yr lease, 2 yr ext (2016)	425.23	141.72	10.63	2.66	80.00%	701715
Terri Lee Smedra	Buck Peak, LLC	T5N-R89W, 6th P.M. Sec 6: Lots 3, 5 SE4NW4 T6N-R89W, 6th P.M. Sec 29: Lot 3 Sec 31: Lot 3,5,6,11 SW4NE4, NW4SE4, NE4SW4, SE4SW4 Sec 32: Lot 4	6/1/2011	5/31/2014 3 yr lease, 2 yr ext (2016)	425.23	47.24	3.54	0.89	80.00%	701712
Mark E. Lyons	Buck Peak, LLC	T5N-R89W, 6th P.M. Sec 6: Lots 3, 5 SE4NW4 T6N-R89W, 6th P.M. Sec 29: Lot 13 Sec 31: Lot 3,5,6,11 SW4NE4, NW4SE4, NE4SW4, SE4SW4 Sec 32: Lot 4	6/1/2011	5/31/2014 3 yr lease, 2 yr ext (2016)	425.23	51.43	3.86	0.96	80.00%	701714

Thomas J. Knez	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 21: Lot 16 Sec 22: Lots 12 & 13	7/10/2011	7/09/2016 5 yr lease, 3 yr ext (2019)	122.97	20.50	1.54	0.38	80.00%	20102823
Helen P. Knez	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 27: Lots 3 & 4 Sec 28: Lot 1	7/17/2011	7/16/2016 5 yr lease, 3 yr ext (2019)	122.93	20.5	1.54	0.38	80.00%	20103517
Gregory J. Knez, Trustee of the Raymond M. & Hellen M. Knez Family Trust	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 21: Lots 11, 14, 15 & 16 Sec 22: Lots 12 & 13 Sec 27: Lots 3 & 4 Sec 28: Lot 1	3/21/2011	3/20/2016 5 yr lease, 3 yr ext (2019)	369.39	61.58	4.62	1.15	80.00%	20103025
Kathy Peters	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 35: Lots 9,10 11,12,13,14,15,16 (S/2)	7/31/2011	7/30/2014 3 yr lease, 3 yr ext (2017)	331.00	110.56	8.29	2.07	80.00%	20103518
Barbara L. Wilaby	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 12: Lots1,2,3,5,6,7,8,9,10,12,13,14,15	10/31/2008 3 years + 2 year ext option	10/30/2013	493.56	208.12	15.61	3.90	80.00%	20090483
Barbara L. Wilaby	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 13: Lots 2,3,4, less tract	10/31/2008 3 years + 2 year ext option	10/30/2013	130.10	30.23	2.27	0.57	80.00%	20090484
Rex Ross Walker	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 34: Lots 1, 7,8,9,10,11,12,13,14,15,16	12/18/2008 3 years + 2 year ext option	12/17/2013	351.36	26.24	1.97	0.49	80.00%	20090151
				EXTENDED			302.97	75.74
Margaret Keith	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 2: Lots 7,8,9,10 less tract (see lease) Sec 2: 15,16,17,18	9/30/2008 5 years + 3 year ext option	9/29/2013	333.57	11.560	0.87	0.22	80.00%	20084242
Margaret Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 105 Sec 21: Lots 1, 2, 8, and 9	9/30/2008 5 years + 3 year ext option	9/29/2013	164.97	12.98	0.97	0.24	80.00%	20084243
Margaret Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 83 Sec 27: Lots 5, 6, 10, 11, 12, 14, 15 & 16 Sec 34: Lots 2, 3 Less acreage (see lease)	9/30/2008 5 years + 3 year ext option	9/29/2013	409.65	16.12	1.21	0.30	80.00%	20084244
Margaret Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 82 Sec 26: Lots 11, 12, 13, & 14 Sec 27: Lots 2, 7, 8 & 9	9/30/2008 5 years + 3 year ext option	9/29/2013	330.85	26.04	1.95	0.49	80.00%	20084245

Margaret Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 70 Sec 21: Lots 4 & 5	9/30/2008 5 years + 3 year ext option	9/29/2013	82.44	9.16	0.69	0.17	80.00%	20084246
Margaret Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assesor's Tract # 69 Sec 21: Lots 3, 6, 7 & 10	9/30/2008 5 years + 3 year ext option	9/29/2013	164.88	17.59	1.32	0.33	80.00%	20084247
James W. Keith	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 2: Lots 7,8,9,10 less tract (see lease) Sec 2: 15,16,17,18	9/30/2008 5 years + 3 year ext option	9/29/2013	333.57	3.86	0.29	0.07	80.00%	20084241
James W. Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 105 Sec 21: Lots 1, 2, 8, and 9	9/30/2008 - 2013 5 years + 3 year ext option	9/29/2013	164.97	4.33	0.32	0.08	80.00%	20084240
James W. Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 83 Sec 27: Lots 5, 6, 10, 11, 12, 14, 15 & 16 Sec 34: Lots 2, 3 Less acreage (see lease)	9/30/2008 5 years + 3 year ext option	9/29/2013	409.65	5.37	0.40	0.10	80.00%	20084239
James W. Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 82 Sec 26: Lots 11, 12, 13, & 14 Sec 27: Lots 2, 7, 8 & 9	9/30/2008 5 years + 3 year ext option	9/29/2013	330.85	8.68	0.65	0.16	80.00%	20084238
James W. Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 70 Sec 21: Lots 4 & 5	9/30/2008 5 years + 3 year ext option	9/29/2013	82.44	3.05	0.23	0.06	80.00%	20084237
James W. Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assesor's Tract # 69 Sec 21: Lots 3, 6, 7 & 10	9/30/2008 5 years + 3 year ext option	9/29/2013	164.88	5.86	0.44	0.11	80.00%	20084236
Charles S. Keith	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 2: Lots 7,8,9,10 less tract (see lease) Sec 2: 15,16,17,18	9/30/2008 5 years + 3 year ext option	9/29/2013	333.57	3.86	0.29	0.07	80.00%	20084235
Charles S. Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 105 Sec 21: Lots 1, 2, 8, and 9	9/30/2008 5 years + 3 year ext option	9/29/2013	164.97	4.33	0.32	0.08	80.00%	20084234
Charles S. Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 83 Sec 27: Lots 5, 6, 10, 11, 12, 14, 15 & 16 Sec 34: Lots 2, 3 Less acreage (see lease)	9/30/2008 5 years + 3 year ext option	9/29/2013	409.65	5.37	0.40	0.10	80.00%	20084233

Charles S. Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 82 Sec 26: Lots 11, 12, 13, & 14 Sec 27: Lots 2, 7, 8 & 9	9/30/2008 5 years + 3 year ext option	9/29/2013	330.85	8.68	0.65	0.16	80.00%	20084232
Charles S. Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 70 Sec 21: Lots 4 & 5	9/30/2008 5 years + 3 year ext option	9/29/2013	82.44	3.05	0.23	0.06	80.00%	20084231
Charles S. Keith	Buck Peak, LLC	T6N-R90W, 6th P.M. Assesor's Tract # 69 Sec 21: Lots 3, 6, 7 & 10	9/30/2008 5 years + 3 year ext option	9/29/2013	164.88	5.86	0.44	0.11	80.00%	20084230
Debra A Ziehm	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 2: Lots 7,8,9,10 less tract (see lease) Sec 2: 15,16,17,18	9/30/2008 5 years + 3 year ext option	9/29/2013	333.57	3.86	0.29	0.07	80.00%	20084253
Debra A Ziehm	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 105 Sec 21: Lots 1, 2, 8, and 9	9/30/2008 - 2013 5 years + 3 year ext option	9/29/2013	164.97	4.33	0.32	0.08	80.00%	20084252
Debra A Ziehm	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 83 Sec 27: Lots 5, 6, 10, 11, 12, 14, 15 & 16 Sec 34: Lots 2, 3 Less acreage (see lease)	9/30/2008 5 years + 3 year ext option	9/29/2013	409.65	5.37	0.40	0.10	80.00%	20084251
Debra A Ziehm	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 82 Sec 26: Lots 11, 12, 13, & 14 Sec 27: Lots 2, 7, 8 & 9	9/30/2008 5 years + 3 year ext option	9/29/2013	330.85	8.68	0.65	0.16	80.00%	20084250
Debra A Ziehm	Buck Peak, LLC	T6N-R90W, 6th P.M. Assessor's Tract # 70 Sec 21: Lots 4 & 5	9/30/2008 5 years + 3 year ext option	9/29/2013	82.44	3.05	0.23	0.06	80.00%	20084249
Debra A Ziehm	Buck Peak, LLC	T6N-R90W, 6th P.M. Assesor's Tract # 69 Sec 21: Lots 3, 6, 7 & 10	9/30/2008 5 years + 3 year ext option	9/29/2013	164.88	5.86	0.44	0.11	80.00%	20084248
Jim F. Kowach	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 12: Lots 1,2,3,5,6,7,8,9,10,12,13,14,15 Sec 13: Lots 2,3,4, less tract (see lease)	10/31/2008	10/30/2013	635.00	238.35	17.88	4.47	80.00%	20084634
Robert Deakins	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 35: S/2	12/8/2008 5 years + 3 year ext option	12/7/2013	331.70	6.91	0.52	0.13	80.00%	20090152
Richard Deakins	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 35: S/2	12/8/2008 5 years + 3 year ext option	12/7/2013	331.70	6.91	0.52	0.13	80.00%	20090482

Kathleen Seely Brennise	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 28: Tract in Lots 11, 12, 14 Sec 31: Lots 5,6,11-14, 19,20, W/2 Sec 32 Lots 7,10-14 Sec 33:Tract in E2W2 Sec 34: Lots 1, 7-16	1/29/2009 5 years + 3 year ext option	1/28/2014	1507.93	145.69	10.93	2.73	80.00%	20091152
Bruce H. and Ann C. Seely	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 28: Tract in Lots 11, 12, 14 Sec 31: Lots 5,6,11-14, 19,20, W/2 Sec 32 Lots 7,10-14 Sec 33:Tract in E2W2 Sec 34: Lots 14, 15, 16	3/1/2009 5 years + 3 year ext option	2/28/2014	1179.60	15.00	1.13	0.28	80.00%	20091997
Bruce H. Seely	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 28: Tract in Lots 11, 12, 14 Sec 31: Lots 5,6,11-14, 19,20, W/2 Sec 32 Lots 7,10-14 Sec 33:Tract in E2W2 Sec 34: Lots 1, 7-16 Sec 35: Lots 4, 5	3/1/2009 5 years + 3 year ext option	2/28/2014	1590.92	146.56	10.99	2.75	80.00%	20091998
David R. and Shirley M. Seely	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 6: Lot 7 Sec 31: Lots 5,6,11-14, 19,20, W/2 Sec 32 Lots 7,10-14 Sec 33:Tract in E2W2 Sec 34: Lots 1, 7-16 Sec 35: Lots 4, 5	3/1/2009 5 years + 3 year ext option	2/28/2014	1465.72	292.60	21.95	5.49	80.00%	20092472
Walter D. Spetter	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 35: Lots 9,10 11,12,13,14,15,16 (S/2)	3/5/2009 5 years + 3 year ext option	3/4/2014	331.70	13.820	1.04	0.26	80.00%	20092059
Donna McMullen	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 35: Lots 9,10 11,12,13,14,15,16 (S/2)	3/5/2009 5 years + 3 year ext option	3/4/2014	331.70	13.82	1.04	0.26	80.00%	20092058
DR Seely, LLC an Idaho Limited Liability Company	Buck Peak, LLC	T6N-R90W, 6th P.M. Sec 31: Lots 5,6,11-14, 19,20, W/2 Sec 32 Lots 7,10-14 Sec 34: Lots 1, 7-16 Sec 35: Lots 4, 5	3/5/2009 5 years + 3 year ext option	3/4/2014	1436.46	169.85	12.74	3.18	80.00%	20092471
Kathleen Seely Brennise	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 3: Lots 6,7,8,9 Sec 4: Lots 5 -13, 15, 16, 18-20 Sec 6: Lots 12,13,14,17,18,19	7/9/2010	7/8/2015	1067.93	123.54	9.27	2.32	80.00%	20102826

Bruce and Ann Seely	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 3: Lots 6,7,8,9 Sec 4: Lots 5 -13, 15, 16, 18-20 Sec 6: Lots 12,13,14,17,18,19	7/9/2010	7/8/2015	1067.93	12.99	0.97	0.24	80.00%	20102591
Bruce Seely, Individually	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 3: Lots 6,7,8,9 Sec 4: Lots 5 -13, 15, 16, 18-20 Sec 6: Lots 12,13,14,17,18,19	7/9/2010	7/8/2015	1067.93	123.54	9.27	2.32	80.00%	20102590
David and Shirley Seely	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 3: Lots 6,7,8,9 Sec 4: Lots 5 -13, 15, 16, 18-20 Sec 6: Lots 12,13,14,17,18,19	7/9/2010	7/8/2015	1067.93	260.18	19.51	4.88	80.00%	20102827
D.R. Seely, LLC	Buck Peak, LLC	T5N-R90W, 6th P.M. Sec 3: Lots 6,7,8,9 Sec 4: Lots 5 -13, 15, 16, 18-20 Sec 6: Lots 12,13,14,17,18,19	7/9/2010	7/8/2015	1067.93	52.04	3.90	0.98	80.00%	20102825
Lease Serial No. COC-73459	Impact Energy Resources, LLC	T5N-R90W, 6th P.M. Section 1: Lot 5, 12, 13	3/1/2009	2/28/2019	125.15	125.15	9.39	2.35	80.00%
						1,933.86	145.04	52.21
						Total Schedule	448.01	112.00
						2.1(a)

EXHIBIT "C"

ASSIGNMENT

STATE OF COLORADO	)
COUNTY OF	)

KNOW ALL MEN BY THESE PRESENTS, that PetroShare Corp., with an office at ___________________hereinafter referred to as "Assignor", for and in consideration of the sum of TEN AND N0/100 DOLLARS ($10.00), the receipt and adequacy of which is hereby acknowledged and full acquittance granted therefor, has granted, sold, conveyed and delivered and does hereby grant, sell, convey and deliver unto LLOCO, L.L.C. with an office at 1001 Ochsner Blvd., Ste 200, Covington, LA 70433 hereinafter referred to as "Assignee", 25% of Assignor's right, title and interest in the following properties (real, personal or mixed) and rights (contractual or otherwise) unless expressly reserved or excluded herein, the following being referred to herein collectively as the Assets:

a)	the oil and gas leases described on Exhibit "A" and "B", attached hereto, in the amounts of the working interests specified thereon (the "Leases");

The rights and interests in, to and under, or derived from, all of the presently existing and valid unitization and pooling agreements and units (including all units formed by voluntary agreement and those formed under the rules, regulations, orders or other official acts of any governmental entity having appropriate jurisdiction) to the extent they relate to any of the Leases;

The rights and interests in, to and under, or derived from, all of the presently existing and valid joint operating agreements, oil sales contracts, casing head gas sales contracts, gas sales contracts, processing contracts, gathering contracts, transportation contracts, easements, rights-of-way, servitudes, surface leases and other contracts to the extent they are described on Exhibit "C", attached hereto (the "Contracts");

The rights and interests in and to all personal property and improvements, including without limitation, tanks, buildings, fixtures, machinery, equipment, pipelines, utility lines, power lines, telephone lines, roads and other appurtenances, to the extent the same are situated upon and/or used or held for use by Seller in connection with the ownership, operation, maintenance and repair of the Leases; and

(f)

The rights and interests in all permits and licenses of any nature owned, held or operated in connection with operations for the exploration and production of oil, gas or other minerals to the extent the same are used or obtained in connection with any of the Leases or other property described in Exhibit "A" ("Permits");

TO HAVE AND TO HOLD the Assets, together with all and singular the rights and appurtenances thereunto in anywise belonging, unto Assignee, its successors and assigns, forever, subject to the following terms and conditions:

1. Special Warrantv of Title. Assignor represents and warrants that the Assets are free and clear of all liens, encumbrances, security interests or other adverse claims arising by, through or under Assignor, but not otherwise. Assignor shall warrant and defend the title to the Assets conveyed to Assignee against every person whomsoever lawfully claims the Assets or any part thereof by, through, or under Assignor, but not otherwise.

2. Successors and Assigns. The terms, covenants and conditions contained in this Assignment shall be binding upon and inure to the benefit of the parties hereto and their respective successors and assigns, and such terms, covenants and conditions shall be covenants running with the land and with each subsequent transfer or assignment of the Assets, or any part thereof.

3. Participation Agreement. This Assignment is made in accordance with and is subject to the terms, covenants and conditions contained in that certain Participation Agreement dated as of _______, 2013, by and between Assignor and Assignee ("Participation Agreement"), all of which shall remain in full force and effect in .accordance with their terms as set forth therein and shall not be deemed to have been merged with this Assignment. Ifthere is a conflict between the provisions of the Participation Agreement and this Assignment, the provisions of the Participation Agreement shall control the rights and obligations of the parties.

4. Further Assurances. Assignor and Assignee agree to take all such further actions and to execute, acknowledge and deliver all such further documents that are necessary or useful in carrying out the purpose of this Assignment.

5. Counteparts. This Assignment is being executed in multiple counterparts each of which shall for all purposes be deemed to be an original and all of which shall constitute one instrument.

ASSIGNOR:

PetroShare Corp.

By: ____________________

Name:

Title:

ASSIGNEE:

By: ____________________

Name: __________________

Title: __________________

STATE OF COLORADO __________________	)
	)	ss.
COUNTY OF ____________________	)

The foregoing instrument was acknowledged before me this ___ day of ___________ , 2013, by ___________ , as ____________________ of PetroShare Corp.

Witness my hand and seal.

My Commission Expires: ____________________	______________________________
	Notary Public

STATE OF LOUISIANNA	)
	)	ss.
COUNTY OF __________	)

The foregoing instrument was acknowledged before me this ___ day of ___________ , 2013, by ___________ , as ____________________ of LLOCO, L.L.C.

Witness my hand and seal.

My Commission Expires: ____________________	______________________________
	Notary Public

SCHEDULE 5.5

LEASE EXTENSION AND DEVELOPMENT AGREEMENT

A.A.P.L. FORM 610 - 1989

MODEL FORM OPERATING AGREEMENT

OPERATING AGREEMENT

DATED

	,	, 2010 ,
		year

OPERATOR	QUICKSILVER RESROUCES INC.

CONTRACTAREA

COUNTY OR PARISH OF

MOFFAT

, STATE OF

COLORADO

AMERICAN ASSOCIATION OF PETROLEUM

LANDMEN, 4100 FOSSIL CREEK BLVD. FORT

WORTH, TEXAS, 76137, APPROVED FORM.

A.A.P.L. NO. 610 – 1989

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

TABLE OF CONTENTS

Article		Page
I.	DEFINITIONS	1
II.	EXHIBITS	1
III.	INTERESTS OF PARTIES	2
	A. OIL AND GAS INTERESTS:	2
	B. INTERESTS OF PARTIES IN COSTS AND PRODUCTION	2
	C. SUBSEQUENTLY CREATED INTERESTS:	2
IV.	TITLES	2
	A. TITLE EXAMINATION	2
	B. LOSS OR FAILURE OF TITLE	3
	1. Failure of Title	3
	2. Loss by Non-Payment or Erroneous Payment of Amount Due	3
	3. Other Losses	3
	4. Curing Title	3
V.	OPERATOR	4
	A. DESIGNATION AND RESPONSIBILITIES OF OPERATOR	4
	B. RESIGNATION OR REMOVAL OF OPERATOR AND SELECTION OF SUCCESSOR	4
	1. Resignation or Removal of Operator	4
	2. Selection of Successor Operator	4
	3. Effect of Bankruptcy	4
	C. EMPLOYEES AND CONTRACTORS	4
	D. RIGHTS AND DUTIES OF OPERATOR:	4
	1. Competitive Rates and Use of Affiliates	4
	2. Discharge of Joint Account Obligations	4
	3. Protection from Liens	4
	4. Custody of Funds	5
	5. Access to Contract Area and Records	5
	6. Filing and Furnishing Governmental Reports	5
	7. Drilling and Testing Operations	5
	8. Cost Estimates	5
	9. Insurance	5
VI.	DRILLING AND DEVELOPMENT	5
	A. INITIAL WELL	5
	B. SUBSEQUENT OPERATIONS:	5
	1. Proposed Operations	5
	2. Operations by Less Than All Parties	6
	3. Stand-By Costs	7
	4. Deepening	8
	5. Sidetracking	8
	6. Order of Preference of Operations	8
	7. Conformity to Spacing Pattern	9
	8. Paying Wells	9
	C. COMPLETION OF WELLS; REWORKING AND PLUGGING BACK	9
	1. Completion	9
	2. Rework, Recomplete or Plug Back	9
	D. OTHER OPERATIONS	9
	E. ABANDONMENT OF WELLS	9
	1. Abandonment of Dry Holes	9
	2. Abandonment of Wells That Have Produced	10
	3. Abandonment of Non-Consent Operations	10
	F. TERMINATION OF OPERATIONS	10
	G. TAKING PRODUCTION IN KIND	10
	(Option 1) Gas Balancing Agreement	10
	(Option 2) No Gas Balancing Agreement	11
VII.	EXPENDITURES AND LIABILITY OF PARTIES	11
	A. LIABILITY OF PARTIES	11
	B. LIENS AND SECURITY INTERESTS	12
	C. ADVANCES	12
	D. DEFAULTS AND REMEDIES	12
	1. Suspension of Rights	13
	2. Suit for Damages	13
	3. Deemed Non-Consent	13
	4. Advance Payment	13
	5. Costs and Attorneys’ Fees	13
	E. RENTALS, SHUT-IN WELL PAYMENTS AND MINIMUM ROYALTIES	13
	F. TAXES	13
VIII.	ACQUISITION, MAINTENANCE OR TRANSFER OF INTEREST	14
	A. SURRENDER OF LEASES	14
	B. RENEWAL OR EXTENSION OF LEASES	14
	C. ACREAGE OR CASH CONTRIBUTIONS	14

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989


	D. ASSIGNMENT; MAINTENANCE OF UNIFORM INTEREST:	15
	E. WAIVER OF RIGHTS TO PARTITION	15
	F. PREFERENTIAL RIGHT TO PURCHASE	15
IX.	INTERNAL REVENUE COEDE ELECTION	15
X.	CLAIMS AND LAWSUITS	15
XI.	FORCE MAJEURE	16
XII.	NOTICES	16
XIII.	TERM OF AGREEMENT	16
XIV.	COMPLIANCE WITH LAWS AND REGULATIONS	16
	A. LAWS, REGULATIONS AND ORDERS	16
	B. GOVERNING LAW	16
	C. REGULATORY AGENCIES:	16
XV.	MISCELLANEOUS	17
	A. EXECUTION	17
	B. SUCCESSORS AND ASSIGNS	17
	C. COUNTERPARTS	17
	D. SEVERABILITY	17
XVI.	OTHER PROVISIONS	17

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	OPERATING AGREEMENT

2	THIS AGREEMENT, entered into by and between Quicksilver Resources Inc. ,

3	hereinafter designated and referred to as "Operator," and the signatory party or parties other than Operator, sometimes

4	hereinafter referred to individually as "Non-Operator," and collectively as "Non-Operators."

5	WITNESSETH:

6	WHEREAS, the parties to this agreement are owners of Oil and Gas Leases and/or Oil and Gas Interests in the land

7	identified in Exhibit "A," and the parties hereto have reached an agreement to explore and develop these Leases and/or Oil

8	and Gas Interests for the production of Oil and Gas to the extent and as hereinafter provided,

9	NOW, THEREFORE, it is agreed as follows:

10	ARTICLE I.

11	DEFINITIONS

12	As used in this agreement, the following words and terms shall have the meanings here ascribed to them:

13	A. The term "AFE" shall mean an Authority for Expenditure prepared by a party to this agreement for the purpose of

14	estimating the costs to be incurred in conducting an operation hereunder.

15	B. The term "Completion" or "Complete" shall mean a single operation intended to complete a well as a producer of Oil

16	and Gas in one or more Zones, including, but not limited to, the setting of production casing, perforating, well stimulation

17	and production testing conducted in such operation.

18	C. The term "Contract Area" shall mean all of the lands, Oil and Gas Leases and/or Oil and Gas Interests intended to be

19	developed and operated for Oil and Gas purposes under this agreement. Such lands, Oil and Gas Leases and Oil and Gas

20	Interests are described in Exhibit "A."

21	D. The term "Deepen" shall mean a single operation whereby a well is drilled to an objective Zone below the deepest

22	Zone in which the well was previously drilled, or below the Deepest Zone proposed in the associated AFE, whichever is the

lesser.

24	E. The terms "Drilling Party" and "Consenting Party" shall mean a party who agrees to join in and pay its share of the

25	cost of any operation conducted under the provisions of this agreement.

26	F. The term "Drilling Unit" shall mean the area fixed for the drilling of one well by order or rule of any state or federal

27	body having authority. If a Drilling Unit is not fixed by any such rule or order, a Drilling Unit shall be the drilling unit as

28	established by the pattern of drilling in the Contract Area unless fixed by express agreement of the Drilling Parties.

29	G. The term "Drillsite" shall mean the Oil and Gas Lease or Oil and Gas Interest on which a proposed well is to be

located.

31	H. The term "Initial Well" shall mean the well required to be drilled by the parties hereto as provided in Article VI.A.

32	I. The term "Non-Consent Well" shall mean a well in which less than all parties have conducted an operation as

33	provided in Article VI.B.2.

34	J. The terms "Non-Drilling Party" and "Non-Consenting Party" shall mean a party who elects not to participate in a

35	proposed operation.

36	K. The term "Oil and Gas" shall mean oil, gas, casinghead gas, gas condensate, and/or all other liquid or gaseous

37	hydrocarbons and other marketable substances produced therewith, unless an intent to limit the inclusiveness of this term is

38	specifically stated.

39	L. The term "Oil and Gas Interests" or "Interests" shall mean unleased fee and mineral interests in Oil and Gas in tracts

40	of land lying within the Contract Area which are owned by parties to this agreement.

41	M. The terms "Oil and Gas Lease," "Lease" and "Leasehold" shall mean the oil and gas leases or interests therein

42	covering tracts of land lying within the Contract Area which are owned by the parties to this agreement.

43	N. The term "Plug Back" shall mean a single operation whereby a deeper Zone is abandoned in order to attempt a

44	Completion in a shallower Zone.

45	O. The term "Recompletion" or "Recomplete" shall mean an operation whereby a Completion in one Zone is abandoned

46	in order to attempt a Completion in a different Zone within the existing wellbore.

47	P. The term "Rework" shall mean an operation conducted in the wellbore of a well after it is Completed to secure,

48	restore, or improve production in a Zone which is currently open to production in the wellbore. Such operations include, but

49	are not limited to, well stimulation operations but exclude any routine repair or maintenance work or drilling, Sidetracking,

50	Deepening, Completing, Recompleting, or Plugging Back of a well.

51	Q. The term "Sidetrack" shall mean the directional control and intentional deviation of a well from vertical so as to

52	change the bottom hole location unless done to straighten the hole or drill around junk in the hole to overcome other

53	mechanical difficulties.

54	R. The term "Zone" shall mean a stratum of earth containing or thought to contain a common accumulation of Oil and

55	Gas separately producible from any other common accumulation of Oil and Gas.

56	Unless the context otherwise clearly indicates, words used in the singular include the plural, the word "person" includes

57	natural and artificial persons, the plural includes the singular, and any gender includes the masculine, feminine, and neuter.

58	ARTICLE II.

EXHIBITS

60	The following exhibits, as indicated below and attached hereto, are incorporated in and made a part hereof:

61	X A. Exhibit "A," shall include the following information:

62	(1) Description of lands subject to this agreement,

63	(2) Restrictions, if any, as to depths, formations, or substances,

64	(3) Parties to agreement with addresses and telephone numbers for notice purposes,

65	(4) Percentages or fractional interests of parties to this agreement,

66	(5) Oil and Gas Leases and/or Oil and Gas Interests subject to this agreement,

67	(6) Burdens on production.

68	____B. Exhibit "B," Form of Lease.

69	X C. Exhibit "C," Accounting Procedure.

70	X D. Exhibit "D," Insurance.

71	____ E. Exhibit "E," Gas Balancing Agreement.

72	____ F. Exhibit "F," Non-Discrimination and Certification of Non-Segregated Facilities.

73	____G. Exhibit "G," Tax Partnership.

74	____H. Other: _____________________________

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	If any provision of any exhibit, except Exhibits "E," "F" and "G," is inconsistent with any provision contained in

2	the body of this agreement, the provisions in the body of this agreement shall prevail.

3	ARTICLE III.

4	INTERESTS OF PARTIES

5	A. Oil and Gas Interests:

6	If any party owns an Oil and Gas Interest in the Contract Area, that Interest shall be treated for all purposes of this

7	agreement and during the term hereof as if it were covered by the form of Oil and Gas Lease attached hereto as Exhibit "B,"

8	and the owner thereof shall be deemed to own both royalty interest in such lease and the interest of the lessee thereunder.

9	B. Interests of Parties in Costs and Production:

10	Unless changed by other provisions, all costs and liabilities incurred in operations under this agreement shall be borne

11	and paid, and all equipment and materials acquired in operations on the Contract Area shall be owned, by the parties as their

12	interests are set forth in Exhibit "A." In the same manner, the parties shall also own all production of Oil and Gas from the

13	Contract Area subject, however, to the payment of royalties and other burdens on production as described hereafter.

14	Operator shall pay or deliver, or

15	cause to be paid or delivered, all burdens on production from the Contract Area

18	Nothing contained in this Article III.B. shall be deemed an assignment or cross-assignment of interests covered hereby,

19	and in the event two or more parties contribute to this agreement jointly owned Leases, the parties' undivided interests in

20	said Leaseholds shall be deemed separate leasehold interests for the purposes of this agreement.

21	C. Subsequently Created Interests:

22	If any party has contributed hereto a Lease or Interest that is burdened with an assignment of production given as security

23	for the payment of money, or if, after the date of this agreement, any party creates an overriding royalty, production

24	payment, net profits interest, assignment of production or other burden payable out of production attributable to its working

25	interest hereunder, such burden shall be deemed a "Subsequently Created Interest."Further, if any party has contributed

26	hereto a Lease or Interest burdened with an overriding royalty, production payment, net profits interests, or other burden

27	payable out of production created prior to the date of this agreement, and such burden is not shown on Exhibit "A," such

28	burden also shall be deemed a Subsequently Created Interest to the extent such burden causes the burdens on such party's

29	Lease or Interest to exceed the amount stipulated in Article III.B. above.

30	The party whose interest is burdened with the Subsequently Created Interest (the "Burdened Party") shall assume and

31	alone bear, pay and discharge the Subsequently Created Interest and shall indemnify, defend and hold harmless the other

32	parties from and against any liability therefor. Further, if the Burdened Party fails to pay, when due, its share of expenses

33	chargeable hereunder, all provisions of Article VII.B. shall be enforceable against the Subsequently Created Interest in the

34	same manner as they are enforceable against the working interest of the Burdened Party. If the Burdened Party is required

35	under this agreement to assign or relinquish to any other party, or parties, all or a portion of its working interest and/or the

36	production attributable thereto, said other party, or parties, shall receive said assignment and/or production free and clear of

37	said Subsequently Created Interest, and the Burdened Party shall indemnify, defend and hold harmless said other party, or

38	parties, from any and all claims and demands for payment asserted by owners of the Subsequently Created Interest.

39	ARTICLE IV.

TITLES

41	A. Title Examination:

42	Title examination shall be made on the Drillsite of any proposed well prior to commencement of drilling operations and,

43	if a majority in interest of the Drilling Parties so request or Operator so elects, title examination shall be made on the entire

44	Drilling Unit, or maximum anticipated Drilling Unit, of the well. The opinion will include the ownership of the working

45	interest, minerals, royalty, overriding royalty and production payments under the applicable Leases.Each party contributing

46	Leases and/or Oil and Gas Interests to be included in the Drillsite or Drilling Unit, if appropriate, shall furnish to Operator

47	all abstracts (including federal lease status reports), title opinions, title papers and curative material in its possession free of

48	charge. All such information not in the possession of or made available to Operator by the parties, but necessary for the

49	examination of the title, shall be obtained by Operator. Operator shall cause title to be examined by attorneys on its staff or

50	by outside attorneys. Copies of all title opinions shall be furnished to each Drilling Party. Costs incurred by Operator in

51	procuring abstracts, fees paid outside attorneys or title examination (including preliminary, supplemental, shut-in royalty

52	opinions and division order title opinions), ( fees paid to outside landmen or brokers) / and other direct charges as provided in Exhibit "C" shall be borne by the Drilling

53	Parties in the proportion that the interest of each Drilling Party bears to the total interest of all Drilling Parties as such

54	interests appear in Exhibit "A." Operator shall make no charge for services rendered by its staff attorneys or other personnel

55	in the performance of the above functions.

56	Operatorshall be responsible for securing curative matter and pooling amendments or agreements required in

57	connection with any title opinion obtained as set forth above. Operator shall be responsible for the preparation

58	and recording of pooling designations or declarations and communitization agreements as well as the conduct of hearings

59	before governmental agencies for the securing of spacing or pooling orders or any other orders necessary or appropriate to

60	the conduct of operations hereunder. This shall not prevent any party from appearing on its own behalf at such hearings.

61	Costs incurred by Operator, including fees paid to outside attorneys, which are associated with hearings before governmental

62	agencies, and which costs are necessary and proper for the activities contemplated under this agreement, shall be direct

63	charges to the joint account and shall not be covered by the administrative overhead charges as provided in Exhibit "C."

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	Operator shall make no charge for services rendered by its staff attorneys or other personnel in the performance of the above

2	functions.

3	No well shall be drilled on the Contract Area until after (1) the title to the Drillsite or Drilling Unit, if appropriate, has

4	been examined as above provided, and (2) the title has been approved by the examining attorney or title has been accepted by

Operator.

6	B. Loss or Failure of Title:

8	3. Losses: All losses of Leases or Interests committed to this agreement, shall be joint losses and shall be borne by all parties in

9	proportion to their interests shown on

10	Exhibit "A." This shall include but not be limited to the loss of any Lease or Interest through failure to develop or because

11	express or implied covenants have not been performed (other than performance which requires only the payment of money),

12	and the loss of any Lease by expiration at the end of its primary term if it is not renewed or extended. There shall be no

13	readjustment of interests in the remaining portion of the Contract Area on account of any joint loss.

14	4. CuringTitle: In the event of a Failure of Title as set forthabove, any

15	Lease or Interest acquired by any party hereto during the ninety

16	(90) day period / following discovery of such failureovering all or a portion of the interest that has failed

17	or was lost shall be offered at cost to the party whose interest has failed or was lost, and the provisions of Article VIII.B.

18	shall not apply to such acquisition.

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	ARTICLE V.

OPERATOR

3	A. Designation and Responsibilities of Operator:

4	Quicksilver Resources Inc. shall be the Operator of the Contract Area, and shall conduct

5	and direct and have full control of all operations on the Contract Area as permitted and required by, and within the limits of

6	this agreement. In its performance of services hereunder for the Non-Operators, Operator shall be an independent contractor

7	not subject to the control or direction of the Non-Operators except as to the type of operation to be undertaken in accordance

8	with the election procedures contained in this agreement. Operator shall not be deemed, or hold itself out as, the agent of the

9	Non-Operators with authority to bind them to any obligation or liability assumed or incurred by Operator as to any third

10	party. Operator shall conduct its activities under this agreement as a reasonable prudent operator, in a good and workmanlike

11	manner, with due diligence and dispatch, in accordance with good oilfield practice, and in compliance with applicable law and

12	regulation, but in no event shall it have any liability as Operator to the other parties for losses sustained or liabilities incurred

13	except such as may result from gross negligence or willful misconduct.

14	B. Resignation or Removal of Operator and Selection of Successor:

15	1. Resignation or Removal of Operator: Operator may resign at any time by giving written notice thereof to Non-Operators.

16	If Operator terminates its legal existence, no longer owns an interest hereunder in the Contract Area, or is no longer capable of

17	serving as Operator, Operator shall be deemed to have resigned without any action by Non-Operators, except the selection of a

18	successor. Operator may be removed only for good cause by the affirmative vote of Non-Operators owning a majority interest

19	based on ownership as shown on Exhibit "A" remaining after excluding the voting interest of Operator; such vote shall not be

20	deemed effective until a written notice has been delivered to the Operator by a Non-Operator detailing the alleged default and

21	Operator has failed to cure the default within thirty (30) days from its receipt of the notice or, if the default concerns an

22	operation then being conducted, within forty-eight (48) hours of its receipt of the notice. For purposes hereof, "good cause" shall

23	mean not only gross negligence or willful misconduct but also the material breach of or inability to meet the standards of

24	operation contained in Article V.A. or material failure or inability to perform its obligations under this agreement.

25	Subject to Article VII.D.1., such resignation or removal shall not become effective until 7:00 o'clock A.M. on the first

26	day of the calendar month following the expiration of ninety (90) days after the giving of notice of resignation by Operator

27	or action by the Non-Operators to remove Operator, unless a successor Operator has been selected and assumes the duties of

28	Operator at an earlier date. Operator, after effective date of resignation or removal, shall be bound by the terms hereof as a

29	Non-Operator. A change of a corporate name or structure of Operator or transfer of Operator's interest to any single

30	subsidiary, parent or successor corporation shall not be the basis for removal of Operator.

31	2. Selection of Successor Operator: Upon the resignation or removal of Operator under any provision of this agreement, a

32	successor Operator shall be selected by the parties. The successor Operator shall be selected from the parties owning an

33	interest in the Contract Area at the time such successor Operator is selected. The successor Operator shall be selected by the

34	affirmative vote of two (2) or more parties owning a majority interest based on ownership as shown on Exhibit "A";

35	provided, however, if an Operator which has been removed or is deemed to have resigned fails to vote or votes only to

36	succeed itself, the successor Operator shall be selected by the affirmative vote of the party or parties owning a majority

37	interest based on ownership as shown on Exhibit "A" remaining after excluding the voting interest of the Operator that was

38	removed or resigned. The former Operator shall promptly deliver to the successor Operator all records and data relating to

39	the operations conducted by the former Operator to the extent such records and data are not already in the possession of the

40	successor operator. Any cost of obtaining or copying the former Operator's records and data shall be charged to the joint

account.

42	3. Effect of Bankruptcy: If Operator becomes insolvent, bankrupt or is placed in receivership, it shall be deemed to have

43	resigned without any action by Non-Operators, except the selection of a successor. If a petition for relief under the federal

44	bankruptcy laws is filed by or against Operator, and the removal of Operator is prevented by the federal bankruptcy court, all

45	Non-Operators and Operator shall comprise an interim operating committee to serve until Operator has elected to reject or

46	assume this agreement pursuant to the Bankruptcy Code, and an election to reject this agreement by Operator as a debtor in

47	possession, or by a trustee in bankruptcy, shall be deemed a resignation as Operator without any action by Non-Operators,

48	except the selection of a successor. During the period of time the operating committee controls operations, all actions shall

49	require the approval of two (2) or more parties owning a majority interest based on ownership as shown on Exhibit "A." In

50	the event there are only two (2) parties to this agreement, during the period of time the operating committee controls

51	operations, a third party acceptable to Operator, Non-Operator and the federal bankruptcy court shall be selected as a

52	member of the operating committee, and all actions shall require the approval of two (2) members of the operating

53	committee without regard for their interest in the Contract Area based on Exhibit "A."

54	C. Employees and Contractors:

55	The number of employees or contractors used by Operator in conducting operations hereunder, their selection, and the

56	hours of labor and the compensation for services performed shall be determined by Operator, and all such employees or

57	contractors shall be the employees or contractors of Operator.

58	D. Rights and Duties of Operator:

59	1. Competitive Rates and Use of Affiliates: All wells drilled on the Contract Area shall be drilled on a competitive

60	contract basis at the usual rates prevailing in the area. If it so desires, Operator may employ its own tools and equipment in

61	the drilling of wells, but its charges therefor shall not exceed the prevailing rates in the area and the rate of such charges

62	shall be agreed upon by the parties in writing before drilling operations are commenced, and such work shall be performed by

63	Operator under the same terms and conditions as are customary and usual in the area in contracts of independent contractors

64	who are doing work of a similar nature. All work performed or materials supplied by affiliates or related parties of Operator

65	shall be performed or supplied at competitive rates, pursuant to written agreement, and in accordance with customs and

66	standards prevailing in the industry.

67	2. Discharge of Joint Account Obligations: Except as herein otherwise specifically provided, Operator shall promptly pay

68	and discharge expenses incurred in the development and operation of the Contract Area pursuant to this agreement and shall

69	charge each of the parties hereto with their respective proportionate shares upon the expense basis provided in Exhibit "C."

70	Operator shall keep an accurate record of the joint account hereunder, showing expenses incurred and charges and credits

71	made and received.

72	3. Protection from Liens: Operator shall pay, or cause to be paid, as and when they become due and payable, all accounts

73	of contractors and suppliers and wages and salaries for services rendered or performed, and for materials supplied on, to or in

74	respect of the Contract Area or any operations for the joint account thereof, and shall keep the Contract Area free from

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	liens and encumbrances resulting therefrom except for those resulting from a bona fide dispute as to services rendered or

2	materials supplied.

3	4. Custody of Funds: Operator shall hold for the account of the Non-Operators any funds of the Non-Operators advanced

4	or paid to the Operator, either for the conduct of operations hereunder or as a result of the sale of production from the

5	Contract Area, and such funds shall remain the funds of the Non-Operators on whose account they are advanced or paid until

6	used for their intended purpose or otherwise delivered to the Non-Operators or applied toward the payment of debts as

7	provided in Article VII.B. Nothing in this paragraph shall be construed to establish a fiduciary relationship between Operator

8	and Non-Operators for any purpose other than to account for Non-Operator funds as herein specifically provided. Nothing in

9	this paragraph shall require the maintenance by Operator of separate accounts for the funds of Non-Operators unless the

10	parties otherwise specifically agree.

11	5. Access to Contract Area and Records: Operator shall, except as otherwise provided herein, permit each Non-Operator

12	or its duly authorized representative, at the Non-Operator's sole risk and cost, full and free access at all reasonable times to

13	all operations of every kind and character being conducted for the joint account on the Contract Area and to the records of

14	operations conducted thereon or production therefrom, including Operator's books and records relating thereto. Such access

15	rights shall not be exercised in a manner interfering with Operator's conduct of an operation hereunder and shall not obligate

16	Operator to furnish any geologic or geophysical data of an interpretive nature unless the cost of preparation of such

17	interpretive data was charged to the joint account. Operator will furnish to each Non-Operator upon request copies of any

18	and all reports and information obtained by Operator in connection with production and related items, including, without

19	limitation, meter and chart reports, production purchaser statements, run tickets and monthly gauge reports, but excluding

20	purchase contracts and pricing information to the extent not applicable to the production of the Non-Operator seeking the

21	information.Any audit of Operator's records relating to amounts expended and the appropriateness of such expenditures

22	shall be conducted in accordance with the audit protocol specified in Exhibit "C."

23	6. Filing and Furnishing Governmental Reports: Operator will file, and upon written request promptly furnish copies to

24	each requesting Non-Operator not in default of its payment obligations, all operational notices, reports or applications

25	required to be filed by local, State, Federal or Indian agencies or authorities having jurisdiction over operations hereunder.

26	Each Non-Operator shall provide to Operator on a timely basis all information necessary to Operator to make such filings.

27	7. Drilling and Testing Operations: The following provisions shall apply to each well drilled hereunder, including but not

28	limited to the Initial Well:

29	(a) Operator will promptly advise Non-Operators of the date on which the well is spudded, or the date on which

30	drilling operations are commenced.

31	(b) Operator will send to Non-Operators such reports, test results and notices regarding the progress of operations on the well

32	as the Non-Operators shall reasonably request, including, but not limited to, daily drilling reports, completion reports, and well logs.

33	(c) Operator shall adequately test all Zones encountered which may reasonably be expected to be capable of producing

34	Oil and Gas in paying quantities as a result of examination of the electric log or any other logs or cores or tests conducted

35	hereunder.

36	8. Cost Estimates: Upon request of any Consenting Party, Operator shall furnish estimates of current and cumulative costs

37	incurred for the joint account at reasonable intervals during the conduct of any operation pursuant to this agreement.

38	Operator shall not be held liable for errors in such estimates so long as the estimates are made in good faith.

39	9. Insurance: At all times while operations are conducted hereunder, Operator shall comply with the workers

40	compensation law of the state where the operations are being conducted; provided, however, that Operator may be a self-

41	insurer for liability under said compensation laws in which event the only charge that shall be made to the joint account shall

42	be as provided in Exhibit "C." Operator shall also carry or provide insurance for the benefit of the joint account of the parties

43	as outlined in Exhibit "D" attached hereto and made a part hereof. Operator shall require all contractors engaged in work on

44	or for the Contract Area to comply with the workers compensation law of the state where the operations are being conducted

45	and to maintain such other insurance as Operator may require.

46	In the event automobile liability insurance is specified in said Exhibit "D," or subsequently receives the approval of the

47	parties, no direct charge shall be made by Operator for premiums paid for such insurance for Operator's automotive

48	equipment.

49	ARTICLE VI.

50	DRILLING AND DEVELOPMENT

51	A. Initial Well:

52	On or before the______ day of ______________ , ____ , Operator shall commence the drilling of the Initial

53	Well at a location on the Contract Area of Operator’s choosing

60	and shall thereafter continue the drilling of the well with due diligence as a vertical well to a depth sufficient to test the Niobrara formation to or to a depth of 7,000 feet, whichever is the lesser depth.

67	The drilling of the Initial Well and the participation therein by all parties is obligatory, subject to Article VI.C.1. as to participation

68	in Completion operations and Article VI.F. as to termination of operations and Article XI as to occurrence of force majeure.

69	B. Subsequent Operations:

70	1. Proposed Operations: If any party hereto should desire to drill any well on the Contract Area other than the Initial Well, or

71	if any party should desire to / complete the Initial Well as a horizontal well or to Rework, Sidetrack, Deepen, Recomplete or Plug Back a dry hole or a well no longer capable of

72	producing in paying quantities in which such party has not otherwise relinquished its interest in the proposed objective Zone under

73	this agreement, the party desiring to drill, Rework, Sidetrack, Deepen, Recomplete or Plug Back such a well shall give written

74	notice of the proposed operation to the parties who have not otherwise relinquished their interest in such objective Zone

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	under this agreement and to all other parties in the case of a proposal for Sidetracking or Deepening, specifying the work to be

2	performed, the location, proposed depth, objective Zone and the estimated cost of the operation. The parties to whom such a

3	notice is delivered shall have thirty (30) days after receipt of the notice within which to notify the party proposing to do the work

4	whether they elect to participate in the cost of the proposed operation. If a drilling rig is on location, notice of a proposal to

5	Rework, Sidetrack, Recomplete, Plug Back or Deepen may be given by telephone and the response period shall be limited to forty-

6	eight (48) hours, exclusive of Saturday, Sunday and legal holidays. Failure of a party to whom such notice is delivered to reply

7	within the period above fixed shall constitute an election by that party not to participate in the cost of the proposed operation.

8	Any proposal by a party to conduct an operation conflicting with the operation initially proposed shall be delivered to all parties

9	within the time and in the manner provided in Article VI.B.6.

10	If all parties to whom such notice is delivered elect to participate in such a proposed operation, the parties shall be

11	contractually committed to participate therein provided such operations are commenced within the time period hereafter set

12	forth, and Operator shall, no later than ninety (90) days after expiration of the notice period of thirty (30) days (or as

13	promptly as practicable after the expiration of the forty-eight (48) hour period when a drilling rig is on location, as the case

14	may be), actually commence the proposed operation and thereafter complete it with due diligence at the risk and expense of

15	the parties participating therein; provided, however, said commencement date may be extended upon written notice of same

16	by Operator to the other parties, for a period of up to thirty (30) additional days if, in the sole opinion of Operator, such

17	additional time is reasonably necessary to obtain permits from governmental authorities, surface rights (including rights-of-

18	way) or appropriate drilling equipment, or to complete title examination or curative matter required for title approval or

19	acceptance. If the actual operation has not been commenced within the time provided (including any extension thereof as

20	specifically permitted herein or in the force majeure provisions of Article XI) and if any party hereto still desires to conduct

21	said operation, written notice proposing same must be resubmitted to the other parties in accordance herewith as if no prior

22	proposal had been made. Those parties that did not participate in the drilling of a well for which a proposal to Deepen or

23	Sidetrack is made hereunder shall, if such parties desire to participate in the proposed Deepening or Sidetracking operation,

24	reimburse the Drilling Parties in accordance with Article VI.B.4. in the event of a Deepening operation and in accordance

25	with Article VI.B.5. in the event of a Sidetracking operation.

26	2. Operations by Less Than All Parties:

27	(a) Determination of Participation. If any party to whom such notice is delivered as provided in Article VI.B.1. or

28	VI.C.1. (Option No. 2) elects not to participate in the proposed operation, then, in order to be entitled to the benefits of this

29	Article, the party or parties giving the notice and such other parties as shall elect to participate in the operation shall, no

30	later than ninety (90) days after the expiration of the notice period of thirty (30) days (or as promptly as practicable after the

31	expiration of the forty-eight (48) hour period when a drilling rig is on location, as the case may be) actually commence the

32	proposed operation and complete it with due diligence. Operator shall perform all work for the account of the Consenting

33	Parties; provided, however, if no drilling rig or other equipment is on location, and if Operator is a Non-Consenting Party,

34	the Consenting Parties shall either: (i) request Operator to perform the work required by such proposed operation for the

35	account of the Consenting Parties, or (ii) designate one of the Consenting Parties as Operator to perform such work. The

36	rights and duties granted to and imposed upon the Operator under this agreement are granted to and imposed upon the party

37	designated as Operator for an operation in which the original Operator is a Non-Consenting Party. Consenting Parties, when

38	conducting operations on the Contract Area pursuant to this Article VI.B.2., shall comply with all terms and conditions of this

39	agreement.

40	If less than all parties approve any proposed operation, the proposing party, immediately after the expiration of the

41	applicable notice period, shall advise all Parties of the total interest of the parties approving such operation and its

42	recommendation as to whether the Consenting Parties should proceed with the operation as proposed. Each Consenting Party,

43	within forty-eight (48) hours (exclusive of Saturday, Sunday, and legal holidays) after delivery of such notice, shall advise the

44	proposing party of its desire to (i) limit participation to such party's interest as shown on Exhibit "A" or (ii) carry only its

45	proportionate part (determined by dividing such party's interest in the Contract Area by the interests of all Consenting Parties in

46	the Contract Area) of Non-Consenting Parties' interests, or (iii) carry its proportionate part (determined as provided in (ii)) of

47	Non-Consenting Parties' interests together with all or a portion of its proportionate part of any Non-Consenting Parties'

48	interests that any Consenting Party did not elect to take. Any interest of Non-Consenting Parties that is not carried by a

49	Consenting Party shall be deemed to be carried by the party proposing the operation if such party does not withdraw its

50	proposal. Failure to advise the proposing party within the time required shall be deemed an election under (i). In the event a

51	drilling rig is on location, notice may be given by telephone, and the time permitted for such a response shall not exceed a

52	total of forty-eight (48) hours (exclusive of Saturday, Sunday and legal holidays). The proposing party, at its election, may

53	withdraw such proposal if there is less than 100% participation and shall notify all parties of such decision within ten (10)

54	days, or within twenty-four (24) hours if a drilling rig is on location, following expiration of the applicable response period.

55	If 100% subscription to the proposed operation is obtained, the proposing party shall promptly notify the Consenting Parties

56	of their proportionate interests in the operation and the party serving as Operator shall commence such operation within the

57	period provided in Article VI.B.1., subject to the same extension right as provided therein.

58	(b) Relinquishment of Interest for Non-Participation. The entire cost and risk of conducting such operations shall be

59	borne by the Consenting Parties in the proportions they have elected to bear same under the terms of the preceding

60	paragraph. Consenting Parties shall keep the leasehold estates involved in such operations free and clear of all liens and

61	encumbrances of every kind created by or arising from the operations of the Consenting Parties. If such an operation results

62	in a dry hole, then subject to Articles VI.B.6. and VI.E.3., the Consenting Parties shall plug and abandon the well and restore

63	the surface location at their sole cost, risk and expense; provided, however, that those Non-Consenting Parties that

64	participated in the drilling, Deepening or Sidetracking of the well shall remain liable for, and shall pay, their proportionate

65	shares of the cost of plugging and abandoning the well and restoring the surface location insofar only as those costs were not

66	increased by the subsequent operations of the Consenting Parties. If any well drilled, Reworked, Sidetracked, Deepened,

67	Recompleted or Plugged Back under the provisions of this Article results in a well capable of producing Oil and/or Gas in

68	paying quantities, the Consenting Parties shall Complete and equip the well to produce at their sole cost and risk, and the

69	well shall then be turned over to Operator (if the Operator did not conduct the operation) and shall be operated by it at the

70	expense and for the account of the Consenting Parties. Upon commencement of operations for the drilling, Reworking,

71	Sidetracking, Recompleting, Deepening or Plugging Back of any such well by Consenting Parties in accordance with the

72	provisions of this Article, each Non-Consenting Party shall be deemed to have relinquished to Consenting Parties, and the

73	Consenting Parties shall own and be entitled to receive, in proportion to their respective interests, all of such Non-

74	Consenting Party's interest in the well and share of production therefrom or, in the case of a Reworking, Sidetracking,

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	Deepening, Recompleting or Plugging Back, or a Completion pursuant to Article VI.C.1. Option No. 2, all of such Non-

2	Consenting Party's interest in the production obtained from the operation in which the Non-Consenting Party did not elect

3	to participate. Such relinquishment shall be effective until the proceeds of the sale of such share, calculated at the well, or

4	market value thereof if such share is not sold (after deducting applicable ad valorem, production, severance, and excise taxes,

5	royalty, overriding royalty and other interests not excepted by Article III.C. payable out of or measured by the production

6	from such well accruing with respect to such interest until it reverts), shall equal the total of the following:

7	(i) 100% of each such Non-Consenting Party's share of the cost of any newly acquired surface equipment

8	beyond the wellhead connections (including but not limited to stock tanks, separators, treaters, pumping equipment and

9	piping), plus 100% of each such Non-Consenting Party's share of the cost of operation of the well commencing with first

10	production and continuing until each such Non-Consenting Party's relinquished interest shall revert to it under other

11	provisions of this Article, it being agreed that each Non-Consenting Party's share of such costs and equipment will be that

12	interest which would have been chargeable to such Non-Consenting Party had it participated in the well from the beginning

13	of the operations; and

14	(ii) 400% of (a) that portion of the costs and expenses of drilling, Reworking, Sidetracking, Deepening,

15	Plugging Back, testing, Completing, and Recompleting, after deducting any cash contributions received under Article VIII.C.,

16	and of (b) that portion of the cost of newly acquired equipment in the well (to and including the wellhead connections),

17	which would have been chargeable to such Non-Consenting Party if it had participated therein.

18	Notwithstanding anything to the contrary in this Article VI.B., if the well does not reach the deepest objective Zone

19	described in the notice proposing the well for reasons other than the encountering of granite or practically impenetrable

20	substance or other condition in the hole rendering further operations impracticable, Operator shall give notice thereof to each

21	Non-Consenting Party who submitted or voted for an alternative proposal under Article VI.B.6. to drill the well to a

22	shallower Zone than the deepest objective Zone proposed in the notice under which the well was drilled, and each such Non-

23	Consenting Party shall have the option to participate in the initial proposed Completion of the well by paying its share of the

24	cost of drilling the well to its actual depth, calculated in the manner provided in Article VI.B.4. (a). If any such Non-

25	Consenting Party does not elect to participate in the first Completion proposed for such well, the relinquishment provisions

26	of this Article VI.B.2. (b) shall apply to such party's interest.

27	(c) Reworking, Recompleting or Plugging Back. An election not to participate in the drilling, Sidetracking or

28	Deepening of a well shall be deemed an election not to participate in any Reworking or Plugging Back operation proposed in

29	such a well, or portion thereof, to which the initial non-consent election applied that is conducted at any time prior to full

30	recovery by the Consenting Parties of the Non-Consenting Party's recoupment amount. Similarly, an election not to

31	participate in the Completing or Recompleting of a well shall be deemed an election not to participate in any Reworking

32	operation proposed in such a well, or portion thereof, to which the initial non-consent election applied that is conducted at

33	any time prior to full recovery by the Consenting Parties of the Non-Consenting Party's recoupment amount. Any such

34	Reworking, Recompleting or Plugging Back operation conducted during the recoupment period shall be deemed part of the

35	cost of operation of said well and there shall be added to the sums to be recouped by the Consenting Parties400% of

36	that portion of the costs of the Reworking, Recompleting or Plugging Back operation which would have been chargeable to

37	such Non-Consenting Party had it participated therein. If such a Reworking, Recompleting or Plugging Back operation is

38	proposed during such recoupment period, the provisions of this Article VI.B. shall be applicable as between said Consenting

39	Parties in said well.

40	(d) Recoupment Matters. During the period of time Consenting Parties are entitled to receive Non-Consenting Party's

41	share of production, or the proceeds therefrom, Consenting Parties shall be responsible for the payment of all ad valorem,

42	production, severance, excise, gathering and other taxes, and all royalty, overriding royalty and other burdens applicable to

43	Non-Consenting Party's share of production not excepted by Article III.C.

44	In the case of any Reworking, Sidetracking, Plugging Back, Recompleting or Deepening operation, the Consenting

45	Parties shall be permitted to use, free of cost, all casing, tubing and other equipment in the well, but the ownership of all

46	such equipment shall remain unchanged; and upon abandonment of a well after such Reworking, Sidetracking, Plugging Back,

46	Recompleting or Deepening, the Consenting Parties shall account for all such equipment to the owners thereof, with each

48	party receiving its proportionate part in kind or in value, less cost of salvage.

49	Within ninety (90) days after the completion of any operation under this Article, the party conducting the operations

50	for the Consenting Parties shall furnish each Non-Consenting Party with an inventory of the equipment in and connected to

51	the well, and an itemized statement of the cost of drilling, Sidetracking, Deepening, Plugging Back, testing, Completing,

52	Recompleting, and equipping the well for production; or, at its option, the operating party, in lieu of an itemized statement

53	of such costs of operation, may submit a detailed statement of monthly billings. Each month thereafter, during the time the

54	Consenting Parties are being reimbursed as provided above, the party conducting the operations for the Consenting Parties

55	shall furnish the Non-Consenting Parties with an itemized statement of all costs and liabilities incurred in the operation of

56	the well, together with a statement of the quantity of Oil and Gas produced from it and the amount of proceeds realized from

57	the sale of the well's working interest production during the preceding month. In determining the quantity of Oil and Gas

58	produced during any month, Consenting Parties shall use industry accepted methods such as but not limited to metering or

59	periodic well tests. Any amount realized from the sale or other disposition of equipment newly acquired in connection with

60	any such operation which would have been owned by a Non-Consenting Party had it participated therein shall be credited

61	against the total unreturned costs of the work done and of the equipment purchased in determining when the interest of such

62	Non-Consenting Party shall revert to it as above provided; and if there is a credit balance, it shall be paid to such Non-

63	Consenting Party.

64	If and when the Consenting Parties recover from a Non-Consenting Party's relinquished interest the amounts provided

65	for above, the relinquished interests of such Non-Consenting Party shall automatically revert to it as of 7:00 a.m. on the day

66	following the day on which such recoupment occurs, and, from and after such reversion, such Non-Consenting Party shall

67	own the same interest in such well, the material and equipment in or pertaining thereto, and the production therefrom as

68	such Non-Consenting Party would have been entitled to had it participated in the drilling, Sidetracking, Reworking,

69	Deepening, Recompleting or Plugging Back of said well. Thereafter, such Non-Consenting Party shall be charged with and

70	shall pay its proportionate part of the further costs of the operation of said well in accordance with the terms of this

71	agreement and Exhibit "C" attached hereto.

72	3. Stand-By Costs: When a well which has been drilled or Deepened has reached its authorized depth and all tests have

73	been completed and the results thereof furnished to the parties, or when operations on the well have been otherwise

74	terminated pursuant to Article VI.F., stand-by costs incurred pending response to a party's notice proposing a Reworking,

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	Sidetracking, Deepening, Recompleting, Plugging Back or Completing operation in such a well (including the period required

2	under Article VI.B.6. to resolve competing proposals) shall be charged and borne as part of the drilling or Deepening

3	operation just completed. Stand-by costs subsequent to all parties responding, or expiration of the response time permitted,

4	whichever first occurs, and prior to agreement as to the participating interests of all Consenting Parties pursuant to the terms

5	of the second grammatical paragraph of Article VI.B.2. (a), shall be charged to and borne as part of the proposed operation,

6	but if the proposal is subsequently withdrawn because of insufficient participation, such stand-by costs shall be allocated

7	between the Consenting Parties in the proportion each Consenting Party's interest as shown on Exhibit "A" bears to the total

8	interest as shown on Exhibit "A" of all Consenting Parties.

9	In the event that notice for a Sidetracking operation is given while the drilling rig to be utilized is on location, any party

10	may request and receive up to five (5) additional days after expiration of the forty-eight hour response period specified in

11	Article VI.B.1. within which to respond by paying for all stand-by costs and other costs incurred during such extended

12	response period; Operator may require such party to pay the estimated stand-by time in advance as a condition to extending

13	the response period. If more than one party elects to take such additional time to respond to the notice, standby costs shall be

14	allocated between the parties taking additional time to respond on a day-to-day basis in the proportion each electing party's

15	interest as shown on Exhibit "A" bears to the total interest as shown on Exhibit "A" of all the electing parties.

16	4. Deepening: If less than all parties elect to participate in a drilling, Sidetracking, or Deepening operation proposed

17	pursuant to Article VI.B.1., the interest relinquished by the Non-Consenting Parties to the Consenting Parties under Article

18	VI.B.2. shall relate only and be limited to the lesser of (i) the total depth actually drilled or (ii) the objective depth or Zone

19	of which the parties were given notice under Article VI.B.1. ("Initial Objective"). Such well shall not be Deepened beyond the

20	Initial Objective without first complying with this Article to afford the Non-Consenting Parties the opportunity to participate

21	in the Deepening operation.

22	In the event any Consenting Party desires to drill or Deepen a Non-Consent Well to a depth below the Initial Objective,

23	such party shall give notice thereof, complying with the requirements of Article VI.B.1., to all parties (including Non-

24	Consenting Parties). Thereupon, Articles VI.B.1. and 2. shall apply and all parties receiving such notice shall have the right to

25	participate or not participate in the Deepening of such well pursuant to said Articles VI.B.1. and 2. If a Deepening operation

26	is approved pursuant to such provisions, and if any Non-Consenting Party elects to participate in the Deepening operation,

27	such Non-Consenting party shall pay or make reimbursement (as the case may be) of the following costs and expenses.

28	(a) If the proposal to Deepen is made prior to the Completion of such well as a well capable of producing in paying

29	quantities, such Non-Consenting Party shall pay (or reimburse Consenting Parties for, as the case may be) that share of costs

30	and expenses incurred in connection with the drilling of said well from the surface to the Initial Objective which Non-

31	Consenting Party would have paid had such Non-Consenting Party agreed to participate therein, plus the Non-Consenting

32	Party's share of the cost of Deepening and of participating in any further operations on the well in accordance with the other

33	provisions of this Agreement; provided, however, all costs for testing and Completion or attempted Completion of the well

34	incurred by Consenting Parties prior to the point of actual operations to Deepen beyond the Initial Objective shall be for the

35	sole account of Consenting Parties.

36	(b) If the proposal is made for a Non-Consent Well that has been previously Completed as a well capable of producing

37	in paying quantities, but is no longer capable of producing in paying quantities, such Non-Consenting Party shall pay (or

38	reimburse Consenting Parties for, as the case may be) its proportionate share of all costs of drilling, Completing, and

39	equipping said well from the surface to the Initial Objective, calculated in the manner provided in paragraph (a) above, less

40	those costs recouped by the Consenting Parties from the sale of production from the well. The Non-Consenting Party shall

41	also pay its proportionate share of all costs of re-entering said well. The Non-Consenting Parties' proportionate part (based

42	on the percentage of such well Non-Consenting Party would have owned had it previously participated in such Non-Consent

43	Well) of the costs of salvable materials and equipment remaining in the hole and salvable surface equipment used in

44	connection with such well shall be determined in accordance with Exhibit "C." If the Consenting Parties have recouped the

45	cost of drilling, Completing, and equipping the well at the time such Deepening operation is conducted, then a Non-

46	Consenting Party may participate in the Deepening of the well with no payment for costs incurred prior to re-entering the

47	well for Deepening

48	The foregoing shall not imply a right of any Consenting Party to propose any Deepening for a Non-Consent Well prior

49	to the drilling of such well to its Initial Objective without the consent of the other Consenting Parties as provided in Article

VI.F.

51	5. Sidetracking: Any party having the right to participate in a proposed Sidetracking operation that does not own an

52	interest in the affected wellbore at the time of the notice shall, upon electing to participate, tender to the wellbore owners its

53	proportionate share (equal to its interest in the Sidetracking operation) of the value of that portion of the existing wellbore

54	to be utilized as follows:

55	(a) If the proposal is for Sidetracking an existing dry hole, reimbursement shall be on the basis of the actual costs

56	incurred in the initial drilling of the well down to the depth at which the Sidetracking operation is initiated.

57	(b) If the proposal is for Sidetracking a well which has previously produced, reimbursement shall be on the basis of

58	such party's proportionate share of drilling and equipping costs incurred in the initial drilling of the well down to the depth

59	at which the Sidetracking operation is conducted, calculated in the manner described in Article VI.B.4(b) above. Such party's

60	proportionate share of the cost of the well's salvable materials and equipment down to the depth at which the Sidetracking

61	operation is initiated shall be determined in accordance with the provisions of Exhibit "C."

62	6. Order of Preference of Operations. Except as otherwise specifically provided in this agreement, if any party desires to

63	propose the conduct of an operation that conflicts with a proposal that has been made by a party under this Article VI, such

64	party shall have fifteen (15) days from delivery of the initial proposal, in the case of a proposal to drill a well or to perform

65	an operation on a well where no drilling rig is on location, or twenty-four (24) hours, exclusive of Saturday, Sunday and legal

66	holidays, from delivery of the initial proposal, if a drilling rig is on location for the well on which such operation is to be

67	conducted, to deliver to all parties entitled to participate in the proposed operation such party's alternative proposal, such

68	alternate proposal to contain the same information required to be included in the initial proposal. Each party receiving such

69	proposals shall elect by delivery of notice to Operator within five (5) days after expiration of the proposal period, or within

70	twenty-four (24) hours (exclusive of Saturday, Sunday and legal holidays) if a drilling rig is on location for the well that is the

71	subject of the proposals, to participate in one of the competing proposals. Any party not electing within the time required

72	shall be deemed not to have voted. The proposal receiving the vote of parties owning the largest aggregate percentage

73	interest of the parties voting shall have priority over all other competing proposals; in the case of a tie vote, the

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	initial proposal shall prevail. Operator shall deliver notice of such result to all parties entitled to participate in the operation

2	within five (5) days after expiration of the election period (or within twenty-four (24) hours, exclusive of Saturday, Sunday

3	and legal holidays, if a drilling rig is on location). Each party shall then have two (2) days (or twenty-four (24) hours if a rig

4	is on location) from receipt of such notice to elect by delivery of notice to Operator to participate in such operation or to

5	relinquish interest in the affected well pursuant to the provisions of Article VI.B.2.; failure by a party to deliver notice within

6	such period shall be deemed an election not to participate in the prevailing proposal.

7	7. Conformity to Spacing Pattern. Notwithstanding the provisions of this Article VI.B.2., it is agreed that no wells shall be

8	proposed to be drilled to or Completed in or produced from a Zone from which a well located elsewhere on the Contract

9	Area is producing, unless such well conforms to the then-existing well spacing pattern for such Zone.

10	8. Paying Wells. No party shall conduct any Reworking, Deepening, Plugging Back, Completion, Recompletion, or

11	Sidetracking operation under this agreement with respect to any well then capable of producing in paying quantities except

12	with the consent of all parties that have not relinquished interests in the well at the time of such operation.

13	C. Completion of Wells; Reworking and Plugging Back:

14	1. Completion: Without the consent of all parties, no well shall be drilled, Deepened or Sidetracked, except any well

15	drilled, Deepened or Sidetracked pursuant to the provisions of Article VI.B.2. of this agreement. Consent to the drilling,

16	Deepening or Sidetracking shall include:

17	oOption No. 1: All necessary expenditures for the drilling, Deepening or Sidetracking, testing, Completing and

18	equipping of the well, including necessary tankage and/or surface facilities.

19	þOption No. 2: All necessary expenditures for the drilling, Deepening or Sidetracking and testing of the well. When

20	such well has reached its authorized depth, and all logs, cores and other tests have been completed, and the results

21	thereof furnished to the parties, Operator shall give immediate notice to the Non-Operators having the right to

22	participate in a Completion attempt whether or not Operator recommends attempting to Complete the well,

23	together with Operator's AFE for Completion costs if not previously provided. The parties receiving such notice

24	shall have forty-eight (48) hours (exclusive of Saturday, Sunday and legal holidays) in which to elect by delivery of

25	notice to Operator to participate in a recommended Completion attempt or to make a Completion proposal with an

26	accompanying AFE. Operator shall deliver any such Completion proposal, or any Completion proposal conflicting

27	with Operator's proposal, to the other parties entitled to participate in such Completion in accordance with the

28	procedures specified in Article VI.B.6. Election to participate in a Completion attempt shall include consent to all

29	necessary expenditures for the Completing and equipping of such well, including necessary tankage and/or surface

30	facilities but excluding any stimulation operation not contained on the Completion AFE. Failure of any party

31	receiving such notice to reply within the period above fixed shall constitute an election by that party not to

32	participate in the cost of the Completion attempt; provided, that Article VI.B.6. shall control in the case of

33	conflicting Completion proposals. If one or more, but less than all of the parties, elect to attempt a Completion, the

34	provision of Article VI.B.2. hereof (the phrase "Reworking, Sidetracking, Deepening, Recompleting or Plugging

35	Back" as contained in Article VI.B.2. shall be deemed to include "Completing") shall apply to the operations

36	thereafter conducted by less than all parties; provided, however, that Article VI.B.2. shall apply separately to each

37	separate Completion or Recompletion attempt undertaken hereunder, and an election to become a Non-Consenting

38	Party as to one Completion or Recompletion attempt shall not prevent a party from becoming a Consenting Party

39	in subsequent Completion or Recompletion attempts regardless whether the Consenting Parties as to earlier

40	Completions or Recompletion have recouped their costs pursuant to Article VI.B.2.; provided further, that any

41	recoupment of costs by a Consenting Party shall be made solely from the production attributable to the Zone in

42	which the Completion attempt is made. Election by a previous Non-Consenting party to participate in a subsequent

43	Completion or Recompletion attempt shall require such party to pay its proportionate share of the cost of salvable

44	materials and equipment installed in the well pursuant to the previous Completion or Recompletion attempt,

45	insofar and only insofar as such materials and equipment benefit the Zone in which such party participates in a

46	Completion attempt.

47	2. Rework, Recomplete or Plug Back: No well shall be Reworked, Recompleted or Plugged Back except a well Reworked,

48	Recompleted, or Plugged Back pursuant to the provisions of Article VI.B.2. of this agreement. Consent to the Reworking,

49	Recompleting or Plugging Back of a well shall include all necessary expenditures in conducting such operations and

50	Completing and equipping of said well, including necessary tankage and/or surface facilities.

51	D. Other Operations:

52	Operator shall not undertake any single project reasonably estimated to require an expenditure in excess of

53	Fifty thousand Dollars ($ 50,000.00) except in connection with the

54	drilling, Sidetracking, Reworking, Deepening, Completing, Recompleting or Plugging Back of a well that has been previously

55	authorized by or pursuant to this agreement; provided, however, that, in case of explosion, fire, flood or other sudden

56	emergency, whether of the same or different nature, Operator may take such steps and incur such expenses as in its opinion

57	are required to deal with the emergency to safeguard life and property but Operator, as promptly as possible, shall report the

58	emergency to the other parties. If Operator prepares an AFE for its own use, Operator shall furnish any Non-Operator so

59	requesting an information copy thereof for any single project costing in excess of Fifty thousand Dollars

60	($ 50,000.00 ). Any party who has not relinquished its interest in a well shall have the right to propose that

61	Operator perform repair work or undertake the installation of artificial lift equipment or ancillary production facilities such as

62	salt water disposal wells or to conduct additional work with respect to a well drilled hereunder or other similar project (but

63	not including the installation of gathering lines or other transportation or marketing facilities, the installation of which shall

64	be governed by separate agreement between the parties) reasonably estimated to require an expenditure in excess of the

65	amount first set forth above in this Article VI.D. (except in connection with an operation required to be proposed under

66	Articles VI.B.1. or VI.C.1. Option No. 2, which shall be governed exclusively be those Articles). Operator shall deliver such

67	proposal to all parties entitled to participate therein. If within thirty (30) days thereof Operator secures the written consent

68	of any party or parties owning at least 75% of the interests of the parties entitled to participate in such operation,

69	each party having the right to participate in such project shall be bound by the terms of such proposal and shall be obligated

70	to pay its proportionate share of the costs of the proposed project as if it had consented to such project pursuant to the terms

71	of the proposal.

72	E. Abandonment of Wells:

73	1. Abandonment of Dry Holes: Except for any well drilled or Deepened pursuant to Article VI.B.2., any well which has

74	been drilled or Deepened under the terms of this agreement and is proposed to be completed as a dry hole shall not be

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	plugged and abandoned without the consent of all parties. Should Operator, after diligent effort, be unable to contact any

2	party, or should any party fail to reply within forty-eight (48) hours (exclusive of Saturday, Sunday and legal holidays) after

3	delivery of notice of the proposal to plug and abandon such well, such party shall be deemed to have consented to the

4	proposed abandonment. All such wells shall be plugged and abandoned in accordance with applicable regulations and at the

5	cost, risk and expense of the parties who participated in the cost of drilling or Deepening such well. Any party who objects to

6	plugging and abandoning such well by notice delivered to Operator within forty-eight (48) hours (exclusive of Saturday,

7	Sunday and legal holidays) after delivery of notice of the proposed plugging shall take over the well as of the end of such

8	forty-eight (48) hour notice period and conduct further operations in search of Oil and/or Gas subject to the provisions of

9	Article VI.B.; failure of such party to provide proof reasonably satisfactory to Operator of its financial capability to conduct

10	such operations or to take over the well within such period or thereafter to conduct operations on such well or plug and

11	abandon such well shall entitle Operator to retain or take possession of the well and plug and abandon the well. The party

12	taking over the well shall indemnify Operator (if Operator is an abandoning party) and the other abandoning parties against

13	liability for any further operations conducted on such well except for the costs of plugging and abandoning the well and

14	restoring the surface, for which the abandoning parties shall remain proportionately liable.

15	2. Abandonment of Wells That Have Produced: Except for any well in which a Non-Consent operation has been

16	conducted hereunder for which the Consenting Parties have not been fully reimbursed as herein provided, any well which has

17	been completed as a producer shall not be plugged and abandoned without the consent of all parties. If all parties consent to

18	such abandonment, the well shall be plugged and abandoned in accordance with applicable regulations and at the cost, risk

19	and expense of all the parties hereto. Failure of a party to reply within sixty (60) days of delivery of notice of proposed

20	abandonment shall be deemed an election to consent to the proposal. If, within sixty (60) days after delivery of notice of the

21	proposed abandonment of any well, all parties do not agree to the abandonment of such well, those wishing to continue its

22	operation from the Zone then open to production shall be obligated to take over the well as of the expiration of the

23	applicable notice period and shall indemnify Operator (if Operator is an abandoning party) and the other abandoning parties

24	against liability for any further operations on the well conducted by such parties. Failure of such party or parties to provide

25	proof reasonably satisfactory to Operator of their financial capability to conduct such operations or to take over the well

26	within the required period or thereafter to conduct operations on such well shall entitle operator to retain or take possession

27	of such well and plug and abandon the well.

28	Parties taking over a well as provided herein shall tender to each of the other parties its proportionate share of the value of

29	the well's salvable material and equipment, determined in accordance with the provisions of Exhibit "C," less the estimated cost

30	of salvaging and the estimated cost of plugging and abandoning and restoring the surface; provided, however, that in the event

31	the estimated plugging and abandoning and surface restoration costs and the estimated cost of salvaging are higher than the

32	value of the well's salvable material and equipment, each of the abandoning parties shall tender to the parties continuing

33	operations their proportionate shares of the estimated excess cost. Each abandoning party shall assign to the non-abandoning

34	parties, without warranty, express or implied, as to title or as to quantity, or fitness for use of the equipment and material, all

35	of its interest in the wellbore of the well and related equipment, together with its interest in the Leasehold insofar and only

36	insofar as such Leasehold covers the right to obtain production from that wellbore in the Zone then open to production. If the

37	interest of the abandoning party is or includes and Oil and Gas Interest, such party shall execute and deliver to the non-

38	abandoning party or parties an oil and gas lease, limited to the wellbore and the Zone then open to production, for a term of

39	one (1) year and so long thereafter as Oil and/or Gas is produced from the Zone covered thereby, such lease to be on the form

40	attached as Exhibit "B." The assignments or leases so limited shall encompass the Drilling Unit upon which the well is located.

41	The payments by, and the assignments or leases to, the assignees shall be in a ratio based upon the relationship of their

42	respective percentage of participation in the Contract Area to the aggregate of the percentages of participation in the Contract

43	Area of all assignees. There shall be no readjustment of interests in the remaining portions of the Contract Area.

44	Thereafter, abandoning parties shall have no further responsibility, liability, or interest in the operation of or production

45	from the well in the Zone then open other than the royalties retained in any lease made under the terms of this Article. Upon

46	request, Operator shall continue to operate the assigned well for the account of the non-abandoning parties at the rates and

47	charges contemplated by this agreement, plus any additional cost and charges which may arise as the result of the separate

48	ownership of the assigned well. Upon proposed abandonment of the producing Zone assigned or leased, the assignor or lessor

49	shall then have the option to repurchase its prior interest in the well (using the same valuation formula) and participate in

50	further operations therein subject to the provisions hereof.

51	3. Abandonment of Non-Consent Operations: The provisions of Article VI.E.1. or VI.E.2. above shall be applicable as

52	between Consenting Parties in the event of the proposed abandonment of any well excepted from said Articles; provided,

53	however, no well shall be permanently plugged and abandoned unless and until all parties having the right to conduct further

54	operations therein have been notified of the proposed abandonment and afforded the opportunity to elect to take over the well

55	in accordance with the provisions of this Article VI.E.; and provided further, that Non-Consenting Parties who own an interest

56	in a portion of the well shall pay their proportionate shares of abandonment and surface restoration cost for such well as

57	provided in Article VI.B.2.(b).

58	F. Termination of Operations:

59	Upon the commencement of an operation for the drilling, Reworking, Sidetracking, Plugging Back, Deepening, testing,

60	Completion or plugging of a well, including but not limited to the Initial Well, such operation shall not be terminated without

61	consent of parties bearing 75% of the costs of such operation; provided, however, that in the event granite or other

62	practically impenetrable substance or condition in the hole is encountered which renders further operations impractical,

63	Operator may discontinue operations and give notice of such condition in the manner provided in Article VI.B.1, and the

64	provisions of Article VI.B. or VI.E. shall thereafter apply to such operation, as appropriate.

65	G. Taking Production in Kind:

66	oOption No. 1: Gas Balancing Agreement Attached

67	Each party shall take in kind or separately dispose of its proportionate share of all Oil and Gas produced from the

68	Contract Area, exclusive of production which may be used in development and producing operations and in preparing and

69	treating Oil and Gas for marketing purposes and production unavoidably lost. Any extra expenditure incurred in the taking

70	in kind or separate disposition by any party of its proportionate share of the production shall be borne by such party. Any

71	party taking its share of production in kind shall be required to pay for only its proportionate share of such part of

72	Operator's surface facilities which it uses.

73	Each party shall execute such division orders and contracts as may be necessary for the sale of its interest in

74	production from the Contract Area, and, except as provided in Article VII.B., shall be entitled to receive payment

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	directly from the purchaser thereof for its share of all production.

2	If any party fails to make the arrangements necessary to take in kind or separately dispose of its proportionate

3	share of the Oil produced from the Contract Area, Operator shall have the right, subject to the revocation at will by

4	the party owning it, but not the obligation, to purchase such Oil or sell it to others at any time and from time to

5	time, for the account of the non-taking party. Any such purchase or sale by Operator may be terminated by

6	Operator upon at least ten (10) days written notice to the owner of said production and shall be subject always to

7	the right of the owner of the production upon at least ten (10) days written notice to Operator to exercise at any

8	time its right to take in kind, or separately dispose of, its share of all Oil not previously delivered to a purchaser.

9	Any purchase or sale by Operator of any other party's share of Oil shall be only for such reasonable periods of time

10	as are consistent with the minimum needs of the industry under the particular circumstances, but in no event for a

11	period in excess of one (1) year.

12	Any such sale by Operator shall be in a manner commercially reasonable under the circumstances but Operator

13	shall have no duty to share any existing market or to obtain a price equal to that received under any existing

14	market. The sale or delivery by Operator of a non-taking party's share of Oil under the terms of any existing

15	contract of Operator shall not give the non-taking party any interest in or make the non-taking party a party to said

16	contract. No purchase shall be made by Operator without first giving the non-taking party at least ten (10) days

17	written notice of such intended purchase and the price to be paid or the pricing basis to be used.

18	All parties shall give timely written notice to Operator of their Gas marketing arrangements for the following

19	month, excluding price, and shall notify Operator immediately in the event of a change in such arrangements.

20	Operator shall maintain records of all marketing arrangements, and of volumes actually sold or transported, which

21	records shall be made available to Non-Operators upon reasonable request.

22	In the event one or more parties' separate disposition of its share of the Gas causes split-stream deliveries to separate

23	pipelines and/or deliveries which on a day-to-day basis for any reason are not exactly equal to a party's respective proportion

24	ate share of total Gas sales to be allocated to it, the balancing or accounting between the parties shall be in accordance with

25	any Gas balancing agreement between the parties hereto, whether such an agreement is attached as Exhibit "E" or is a

26	separate agreement. Operator shall give notice to all parties of the first sales of Gas from any well under this agreement.

27	þ Option No. 2: No Gas Balancing Agreement:

28	Operator shall be soley responsible for marketing all Oil and Gas produced from

29	the Contract Area, exclusive of production which may be used in development and producing operations and in

30	preparing and treating Oil and Gas for marketing purposes and production unavoidably lost.

31	Each party shall execute such division orders and contracts as may be necessary for the sale of its interest in

32	production from the Contract Area.

34	Any such sale by Operator shall be in a manner commercially reasonable under the circumstances. The sale or delivery by

35	Operator of a non-taking party's share of production under the terms of any existing contract of Operator shall not

36	give the non-taking party any interest in or make the non-taking party a party to said contract.

38	ARTICLE VII.

39	EXPENDITURES AND LIABILITY OF PARTIES

40	A. Liability of Parties:

41	The liability of the parties shall be several, not joint or collective. Each party shall be responsible only for its obligations,

42	and shall be liable only for its proportionate share of the costs of developing and operating the Contract Area. Accordingly, the

43	liens granted among the parties in Article VII.B. are given to secure only the debts of each severally, and no party shall have

44	any liability to third parties hereunder to satisfy the default of any other party in the payment of any expense or obligation

45	hereunder. It is not the intention of the parties to create, nor shall this agreement be construed as creating, a mining or other

46	partnership, joint venture, agency relationship or association, or to render the parties liable as partners, co-venturers, or

47	principals. In their relations with each other under this agreement, the parties shall not be considered fiduciaries or to have

48	established a confidential relationship but rather shall be free to act on an arm's-length basis in accordance with their own

49	respective self-interest, subject, however, to the obligation of the parties to act in good faith in their dealings with each other

50	with respect to activities hereunder.

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	B. Liens and Security Interests:

2	Each party grants to the other parties hereto a lien upon any interest it now owns or hereafter acquires in Oil and Gas

3	Leases and Oil and Gas Interests in the Contract Area, and a security interest and/or purchase money security interest in any

4	interest it now owns or hereafter acquires in the personal property and fixtures on or used or obtained for use in connection

5	therewith, to secure performance of all of its obligations under this agreement including but not limited to payment of expense,

6	interest and fees, the proper disbursement of all monies paid hereunder, the assignment or relinquishment of interest in Oil

7	and Gas Leases as required hereunder, and the proper performance of operations hereunder. Such lien and security interest

8	granted by each party hereto shall include such party's leasehold interests, working interests, operating rights, and royalty and

9	overriding royalty interests in the Contract Area now owned or hereafter acquired and in lands pooled or unitized therewith or

10	otherwise becoming subject to this agreement, the Oil and Gas when extracted therefrom and equipment situated thereon or

11	used or obtained for use in connection therewith (including, without limitation, all wells, tools, and tubular goods), and accounts

12	(including, without limitation, accounts arising from gas imbalances or from the sale of Oil and/or Gas at the wellhead),

13	contract rights, inventory and general intangibles relating thereto or arising therefrom, and all proceeds and products of the

14	foregoing.

15	To perfect the lien and security agreement provided herein, each party hereto shall execute and acknowledge the recording

16	supplement and/or any financing statement prepared and submitted by any party hereto in conjunction herewith or at any time

17	following execution hereof, and Operator is authorized to file this agreement or the recording supplement executed herewith as

18	a lien or mortgage in the applicable real estate records and as a financing statement with the proper officer under the Uniform

19	Commercial Code in the state in which the Contract Area is situated and such other states as Operator shall deem appropriate

20	to perfect the security interest granted hereunder. Any party may file this agreement, the recording supplement executed

21	herewith, or such other documents as it deems necessary as a lien or mortgage in the applicable real estate records and/or a

22	financing statement with the proper officer under the Uniform Commercial Code.

23	Each party represents and warrants to the other parties hereto that the lien and security interest granted by such party to

24	the other parties shall be a first and prior lien, and each party hereby agrees to maintain the priority of said lien and security

25	interest against all persons acquiring an interest in Oil and Gas Leases and Interests covered by this agreement by, through or

26	under such party. All parties acquiring an interest in Oil and Gas Leases and Oil and Gas Interests covered by this agreement,

27	whether by assignment, merger, mortgage, operation of law, or otherwise, shall be deemed to have taken subject

28	to the lien and security interest granted by this Article VII.B. as to all obligations attributable to such interest hereunder

29	whether or not such obligations arise before or after such interest is acquired.

30	To the extent that parties have a security interest under the Uniform Commercial Code of the state in which the

31	Contract Area is situated, they shall be entitled to exercise the rights and remedies of a secured party under the Code.

32	The bringing of a suit and the obtaining of judgment by a party for the secured indebtedness shall not be deemed an

33	election of remedies or otherwise affect the lien rights or security interest as security for the payment thereof.In

34	addition, upon default by any party in the payment of its share of expenses, interests or fees, or upon the improper use

35	of funds by the Operator, the other parties shall have the right, without prejudice to other rights or remedies, to collect

36	from the purchaser the proceeds from the sale of such defaulting party's share of Oil and Gas until the amount owed by

37	such party, plus interest as provided in "Exhibit C," has been received, and shall have the right to offset the amount

38	owed against the proceeds from the sale of such defaulting party's share of Oil and Gas. All purchasers of production

39	may rely on a notification of default from the non-defaulting party or parties stating the amount due as a result of the

40	default, and all parties waive any recourse available against purchasers for releasing production proceeds as provided in

41	this paragraph.

42	If any party fails to pay its share of cost within one hundred twenty (120) days after rendition of a statement therefor by

43	Operator, the non-defaulting parties, including Operator, shall upon request by Operator, pay the unpaid amount in the

44	proportion that the interest of each such party bears to the interest of all such parties. The amount paid by each party so

45	paying its share of the unpaid amount shall be secured by the liens and security rights described in Article VII.B., and each

46	paying party may independently pursue any remedy available hereunder or otherwise.

47	If any party does not perform all of its obligations hereunder, and the failure to perform subjects such party to foreclosure

48	or execution proceedings pursuant to the provisions of this agreement, to the extent allowed by governing law, the defaulting

49	party waives any available right of redemption from and after the date of judgment, any required valuation or appraisement

50	of the mortgaged or secured property prior to sale, any available right to stay execution or to require a marshaling of assets

51	and any required bond in the event a receiver is appointed. In addition, to the extent permitted by applicable law, each party

52	hereby grants to the other parties a power of sale as to any property that is subject to the lien and security rights granted

53	hereunder, such power to be exercised in the manner provided by applicable law or otherwise in a commercially reasonable

54	manner and upon reasonable notice.

55	Each party agrees that the other parties shall be entitled to utilize the provisions of Oil and Gas lien law or other lien

56	law of any state in which the Contract Area is situated to enforce the obligations of each party hereunder. Without limiting

57	the generality of the foregoing, to the extent permitted by applicable law, Non-Operators agree that Operator may invoke or

58	utilize the mechanics' or materialmen's lien law of the state in which the Contract Area is situated in order to secure the

59	payment to Operator of any sum due hereunder for services performed or materials supplied by Operator.

60	C. Advances:

61	Operator, at its election, shall have the right from time to time to demand and receive from one or more of the other

62	parties payment in advance of their respective shares of the estimated amount of the expense to be incurred in operations

63	hereunder during the next succeeding month, which right may be exercised only by submission to each such party of an

64	itemized statement of such estimated expense, together with an invoice for its share thereof. Each such statement and invoice

65	for the payment in advance of estimated expense shall be submitted on or before the 20th day of the next preceding month.

66	Each party shall pay to Operator its proportionate share of such estimate within fifteen (15) days after such estimate and

67	invoice is received. If any party fails to pay its share of said estimate within said time, the amount due shall bear interest as

68	provided in Exhibit "C" until paid. Proper adjustment shall be made monthly between advances and actual expense to the end

69	that each party shall bear and pay its proportionate share of actual expenses incurred, and no more.

70	D. Defaults and Remedies:

71	If any party fails to discharge any financial obligation under this agreement, including without limitation the failure to

72	make any advance under the preceding Article VII.C. or any other provision of this agreement, within the period required for

73	such payment hereunder, then in addition to the remedies provided in Article VII.B. or elsewhere in this agreement, the

74	remedies specified below shall be applicable. For purposes of this Article VII.D., all notices and elections shall be delivered

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	only by Operator, except that Operator shall deliver any such notice and election requested by a non-defaulting Non-Operator,

2	and when Operator is the party in default, the applicable notices and elections can be delivered by any Non-Operator.

3	Election of any one or more of the following remedies shall not preclude the subsequent use of any other remedy specified

4	below or otherwise available to a non-defaulting party.

5	1. Suspension of Rights: Any party may deliver to the party in default a Notice of Default, which shall specify the default,

6	specify the action to be taken to cure the default, and specify that failure to take such action will result in the exercise of one

7	or more of the remedies provided in this Article. If the default is not cured within thirty (30) days of the delivery of such

8	Notice of Default, all of the rights of the defaulting party granted by this agreement may upon notice be suspended until the

9	default is cured, without prejudice to the right of the non-defaulting party or parties to continue to enforce the obligations of

10	the defaulting party previously accrued or thereafter accruing under this agreement. If Operator is the party in default, the

11	Non-Operators shall have in addition the right, by vote of Non-Operators owning a majority in interest in the Contract Area

12	after excluding the voting interest of Operator, to appoint a new Operator effective immediately. The rights of a defaulting

13	party that may be suspended hereunder at the election of the non-defaulting parties shall include, without limitation, the right

14	to receive information as to any operation conducted hereunder during the period of such default, the right to elect to

15	participate in an operation proposed under Article VI.B. of this agreement, the right to participate in an operation being

16	conducted under this agreement even if the party has previously elected to participate in such operation, and the right to

17	receive proceeds of production from any well subject to this agreement.

18	2. Suit for Damages: Non-defaulting parties or Operator for the benefit of non-defaulting parties may sue (at joint

19	account expense) to collect the amounts in default, plus interest accruing on the amounts recovered from the date of default

20	until the date of collection at the rate specified in Exhibit "C" attached hereto. Nothing herein shall prevent any party from

21	suing any defaulting party to collect consequential damages accruing to such party as a result of the default.

22	3. Deemed Non-Consent: The non-defaulting party may deliver a written Notice of Non-Consent Election to the

23	defaulting party at any time after the expiration of the thirty-day cure period following delivery of the Notice of Default, in

24	which event if the billing is for the drilling a new well or the Plugging Back, Sidetracking, Reworking or Deepening of a

25	well which is to be or has been plugged as a dry hole, or for the Completion or Recompletion of any well, the defaulting

26	party will be conclusively deemed to have elected not to participate in the operation and to be a Non-Consenting Party with

27	respect thereto under Article VI.B. or VI.C., as the case may be, to the extent of the costs unpaid by such party,

28	notwithstanding any election to participate theretofore made. If election is made to proceed under this provision, then the

29	non-defaulting parties may not elect to sue for the unpaid amount pursuant to Article VII.D.2.

30	Until the delivery of such Notice of Non-Consent Election to the defaulting party, such party shall have the right to cure

31	its default by paying its unpaid share of costs plus interest at the rate set forth in Exhibit "C," provided, however, such

32	payment shall not prejudice the rights of the non-defaulting parties to pursue remedies for damages incurred by the non-

33	defaulting parties as a result of the default. Any interest relinquished pursuant to this Article VII.D.3. shall be offered to the

34	non-defaulting parties in proportion to their interests, and the non-defaulting parties electing to participate in the ownership

35	of such interest shall be required to contribute their shares of the defaulted amount upon their election to participate therein.

36	4. Advance Payment: If a default is not cured within thirty (30) days of the delivery of a Notice of Default, Operator, or

37	Non-Operators if Operator is the defaulting party, may thereafter require advance payment from the defaulting

38	party of such defaulting party's anticipated share of any item of expense for which Operator, or Non-Operators, as the case may

39	be, would be entitled to reimbursement under any provision of this agreement, whether or not such expense was the subject of

40	the previous default. Such right includes, but is not limited to, the right to require advance payment for the estimated costs of

41	drilling a well or Completion of a well as to which an election to participate in drilling or Completion has been made. If the

42	defaulting party fails to pay the required advance payment, the non-defaulting parties may pursue any of the remedies provided

43	in the Article VII.D. or any other default remedy provided elsewhere in this agreement. Any excess of funds advanced remaining

44	when the operation is completed and all costs have been paid shall be promptly returned to the advancing party.

45	5. Costs and Attorneys' Fees: In the event any party is required to bring legal proceedings to enforce any financial

46	obligation of a party hereunder, the prevailing party in such action shall be entitled to recover all court costs, costs of

47	collection, and a reasonable attorney's fee, which the lien provided for herein shall also secure.

48	E. Rentals, Shut-in Well Payments and Minimum Royalties:

49	Rentals, shut-in well payments and minimum royalties which may be required under the terms of any lease shall be paid

50	by the party or parties who subjected such lease to this agreement at its or their expense. In the event two or more parties

51	own and have contributed interests in the same lease to this agreement, such parties may designate one of such parties to

52	make said payments for and on behalf of all such parties. Any party may request, and shall be entitled to receive, proper

53	evidence of all such payments. In the event of failure to make proper payment of any rental, shut-in well payment or

54	minimum royalty through mistake or oversight where such payment is required to continue the lease in force, any loss which

55	results from such non-payment shall be borne in accordance with the provisions of Article IV.B.2.

56	Operator shall notify Non-Operators of the anticipated completion of a shut-in well, or the shutting in or return to

57	production of a producing well, at least five (5) days (excluding Saturday, Sunday, and legal holidays) prior to taking such

58	action, or at the earliest opportunity permitted by circumstances, but assumes no liability for failure to do so. In the event of

59	failure by Operator to so notify Non-Operators, the loss of any lease contributed hereto by Non-Operators for failure to make

60	timely payments of any shut-in well payment shall be borne jointly by the parties hereto under the provisions of Article 61

IV.B.3.

F. Taxes:

63	Beginning with the first calendar year after the effective date hereof, Operator shall render for ad valorem taxation all

64	property subject to this agreement which by law should be rendered for such taxes, and it shall pay all such taxes assessed

65	thereon before they become delinquent. Prior to the rendition date, each Non-Operator shall furnish Operator information as

66	to burdens (to include, but not be limited to, royalties, overriding royalties and production payments) on Leases and Oil and

67	Gas Interests contributed by such Non-Operator. If the assessed valuation of any Lease is reduced by reason of its being

68	subject to outstanding excess royalties, overriding royalties or production payments, the reduction in ad valorem taxes

69	resulting therefrom shall inure to the benefit of the owner or owners of such Lease, and Operator shall adjust the charge to

70	such owner or owners so as to reflect the benefit of such reduction. If the ad valorem taxes are based in whole or in part

71	upon separate valuations of each party's working interest, then notwithstanding anything to the contrary herein, charges to

72	the joint account shall be made and paid by the parties hereto in accordance with the tax value generated by each party's

73	working interest. Operator shall bill the other parties for their proportionate shares of all tax payments in the manner

74	provided in Exhibit "C."

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	If Operator considers any tax assessment improper, Operator may, at its discretion, protest within the time and manner

2	prescribed by law, and prosecute the protest to a final determination, unless all parties agree to abandon the protest prior to final

3	determination. During the pendency of administrative or judicial proceedings, Operator may elect to pay, under protest, all such taxes

4	and any interest and penalty. When any such protested assessment shall have been finally determined, Operator shall pay the tax for

5	the joint account, together with any interest and penalty accrued, and the total cost shall then be assessed against the parties, and be

6	paid by them, as provided in Exhibit "C."

7	Each party shall pay or cause to be paid all production, severance, excise, gathering and other taxes imposed upon or with respect

8	to the production or handling of such party's share of Oil and Gas produced under the terms of this agreement.

9	ARTICLE VIII.

10	ACQUISITION, MAINTENANCE OR TRANSFER OF INTEREST

11	A. Surrender of Leases:

12	The Leases covered by this agreement, insofar as they embrace acreage in the Contract Area, shall not be surrendered in whole

13	or in part unless all parties consent thereto.

14	However, should any party desire to surrender its interest in any Lease or in any portion thereof, such party shall give written

15	notice of the proposed surrender to all parties, and the parties to whom such notice is delivered shall have thirty (30) days after

16	delivery of the notice within which to notify the party proposing the surrender whether they elect to consent thereto. Failure of a

17	party to whom such notice is delivered to reply within said 30-day period shall constitute a consent to the surrender of the Leases

18	described in the notice. If all parties do not agree or consent thereto, the party desiring to surrender shall assign, without express or

19	implied warranty of title, all of its interest in such Lease, or portion thereof, and any well, material and equipment which may be

20	located thereon and any rights in production thereafter secured, to the parties not consenting to such surrender. If the interest of the

21	assigning party is or includes an Oil and Gas Interest, the assigning party shall execute and deliver to the party or parties not

22	consenting to such surrender an oil and gas lease covering such Oil and Gas Interest for a term of one (1) year and so long

23	thereafter as Oil and/or Gas is produced from the land covered thereby, such lease to be on the form attached hereto as Exhibit "B."

24	Upon such assignment or lease, the assigning party shall be relieved from all obligations thereafter accruing, but not theretofore

25	accrued, with respect to the interest assigned or leased and the operation of any well attributable thereto, and the assigning party

26	shall have no further interest in the assigned or leased premises and its equipment and production other than the royalties retained

27	in any lease made under the terms of this Article. The party assignee or lessee shall pay to the party assignor or lessor the

28	reasonable salvage value of the latter's interest in any well's salvable materials and equipment attributable to the assigned or leased

29	acreage. The value of all salvable materials and equipment shall be determined in accordance with the provisions of Exhibit "C," less

30	the estimated cost of salvaging and the estimated cost of plugging and abandoning and restoring the surface. If such value is less

31	than such costs, then the party assignor or lessor shall pay to the party assignee or lessee the amount of such deficit. If the

32	assignment or lease is in favor of more than one party, the interest shall be shared by such parties in the proportions that the

33	interest of each bears to the total interest of all such parties. If the interest of the parties to whom the assignment is to be made

34	varies according to depth, then the interest assigned shall similarly reflect such variances.

35	Any assignment, lease or surrender made under this provision shall not reduce or change the assignor's, lessor's or surrendering

36	party's interest as it was immediately before the assignment, lease or surrender in the balance of the Contract Area; and the acreage

37	assigned, leased or surrendered, and subsequent operations thereon, shall not thereafter be subject to the terms and provisions of this

38	agreement but shall be deemed subject to an Operating Agreement in the form of this agreement.

39	B. Renewal or Extension of Leases:

40	If any party secures a renewal or replacement of an Oil and Gas Lease or Interest subject to this agreement, then all other parties

41	shall be notified promptly upon such acquisition or, in the case of a replacement Lease taken before expiration of an existing Lease,

42	promptly upon expiration of the existing Lease. The parties notified shall have the right for a period of thirty (30) days following

43	delivery of such notice in which to elect to participate in the ownership of the renewal or replacement Lease, insofar as such Lease

44	affects lands within the Contract Area, by paying to the party who acquired it their proportionate shares of the acquisition cost

45	allocated to that part of such Lease within the Contract Area, which shall be in proportion to the interest held at that time by the

46	parties in the Contract Area. Each party who participates in the purchase of a renewal or replacement Lease shall be given an

47	assignment of its proportionate interest therein by the acquiring party.

48	If some, but less than all, of the parties elect to participate in the purchase of a renewal or replacement Lease, it shall be owned

49	by the parties who elect to participate therein, in a ratio based upon the relationship of their respective percentage of participation in

50	the Contract Area to the aggregate of the percentages of participation in the Contract Area of all parties participating in the

51	purchase of such renewal or replacement Lease. The acquisition of a renewal or replacement Lease by any or all of the parties hereto

52	shall not cause a readjustment of the interests of the parties stated in Exhibit "A," but any renewal or replacement Lease in which

53	less than all parties elect to participate shall not be subject to this agreement but shall be deemed subject to a separate Operating

54	Agreement in the form of this agreement.

55	If the interests of the parties in the Contract Area vary according to depth, then their right to participate proportionately in

56	renewal or replacement Leases and their right to receive an assignment of interest shall also reflect such depth variances.

57	The provisions of this Article shall apply to renewal or replacement Leases whether they are for the entire interest covered by

58	the expiring Lease or cover only a portion of its area or an interest therein. Any renewal or replacement Lease taken before the

59	expiration of its predecessor Lease, or taken or contracted for or becoming effective within six (6) months after the expiration of the

60	existing Lease, shall be subject to this provision so long as this agreement is in effect at the time of such acquisition or at the time

61	the renewal or replacement Lease becomes effective; but any Lease taken or contracted for more than six (6) months after the

62	expiration of an existing Lease shall not be deemed a renewal or replacement Lease and shall not be subject to the provisions of this

63	agreement.

64	The provisions in this Article shall also be applicable to extensions of Oil and Gas Leases.

65	C. Acreage or Cash Contributions:

66	While this agreement is in force, if any party contracts for a contribution of cash towards the drilling of a well or any other

67	operation on the Contract Area, such contribution shall be paid to the party who conducted the drilling or other operation and shall

68	be applied by it against the cost of such drilling or other operation. If the contribution be in the form of acreage, the party to whom

69	the contribution is made shall promptly tender an assignment of the acreage, without warranty of title, to the Drilling Parties in the

70	proportions said Drilling Parties shared the cost of drilling the well. Such acreage shall become a separate Contract Area and, to the

71	extent possible, be governed by provisions identical to this agreement. Each party shall promptly notify all other parties of any

72	acreage or cash contributions it may obtain in support of any well or any other operation on the Contract Area. The above

73	provisions shall also be applicable to optional rights to earn acreage outside the Contract Area which are in support of well drilled

74	inside Contract Area.

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	If any party contracts for any consideration relating to disposition of such party's share of substances produced hereunder,

2	such consideration shall not be deemed a contribution as contemplated in this Article VIII.C.

3	D. Assignment; Maintenance of Uniform Interest:

4	For the purpose of maintaining uniformity of ownership in the Contract Area in the Oil and Gas Leases, Oil and Gas

5	Interests, wells, equipment and production covered by this agreement no party shall sell, encumber, transfer or make other

6	disposition of its interest in the Oil and Gas Leases and Oil and Gas Interests embraced within the Contract Area or in wells,

7	equipment and production unless such disposition covers either:

8	1. the entire interest of the party in all Oil and Gas Leases, Oil and Gas Interests, wells, equipment and production; or

9	2. an equal undivided percent of the party's present interest in all Oil and Gas Leases, Oil and Gas Interests, wells,

10	equipment and production in the Contract Area.

11	Every sale, encumbrance, transfer or other disposition made by any party shall be made expressly subject to this agreement

12	and shall be made without prejudice to the right of the other parties, and any transferee of an ownership interest in any Oil and

13	Gas Lease or Interest shall be deemed a party to this agreement as to the interest conveyed from and after the effective date of

14	the transfer of ownership; provided, however, that the other parties shall not be required to recognize any such sale,

15	encumbrance, transfer or other disposition for any purpose hereunder until thirty (30) days after they have received a copy of the

16	instrument of transfer or other satisfactory evidence thereof in writing from the transferor or transferee. No assignment or other

17	disposition of interest by a party shall relieve such party of obligations previously incurred by such party hereunder with respect

18	to the interest transferred, including without limitation the obligation of a party to pay all costs attributable to an operation

19	conducted hereunder in which such party has agreed to participate prior to making such assignment, and the lien and security

20	interest granted by Article VII.B. shall continue to burden the interest transferred to secure payment of any such obligations.

21	If, at any time the interest of any party is divided among and owned by four or more co-owners, Operator, at its discretion,

22	may require such co-owners to appoint a single trustee or agent with full authority to receive notices, approve expenditures,

23	receive billings for and approve and pay such party's share of the joint expenses, and to deal generally with, and with power to

24	bind, the co-owners of such party's interest within the scope of the operations embraced in this agreement; however, all such co-

25	owners shall have the right to enter into and execute all contracts or agreements for the disposition of their respective shares of

26	the Oil and Gas produced from the Contract Area and they shall have the right to receive, separately, payment of the sale

27	proceeds thereof.

28	E. Waiver of Rights to Partition:

29	If permitted by the laws of the state or states in which the property covered hereby is located, each party hereto owning an

30	undivided interest in the Contract Area waives any and all rights it may have to partition and have set aside to it in severalty its

31	undivided interest therein.

23	F. Preferential Right to Purchase:

33	o (Optional; Check if applicable.)

34	Should any party desire to sell all or any part of its interests under this agreement, or its rights and interests in the Contract

35	Area, it shall promptly give written notice to the other parties, with full information concerning its proposed disposition, which

36	shall include the name and address of the prospective transferee (who must be ready, willing and able to purchase), the purchase

37	price, a legal description sufficient to identify the property, and all other terms of the offer. The other parties shall then have an

38	optional prior right, for a period of ten (10) days after the notice is delivered, to purchase for the stated consideration on the

38	same terms and conditions the interest which the other party proposes to sell; and, if this optional right is exercised, the

40	purchasing parties shall share the purchased interest in the proportions that the interest of each bears to the total interest of all

41	purchasing parties. However, there shall be no preferential right to purchase in those cases where any party wishes to mortgage

42	its interests, or to transfer title to its interests to its mortgagee in lieu of or pursuant to foreclosure of a mortgage of its interests,

43	or to dispose of its interests by merger, reorganization, consolidation, or by sale of all or substantially all of its Oil and Gas assets

44	to any party, or by transfer of its interests to a subsidiary or parent company or to a subsidiary of a parent company, or to any

45	company in which such party owns a majority of the stock.

46	ARTICLE IX.

47	INTERNAL REVENUE CODE ELECTION

48	If, for federal income tax purposes, this agreement and the operations hereunder are regarded as a partnership, and if the

49	parties have not otherwise agreed to form a tax partnership pursuant to Exhibit "G" or other agreement between them, each

50	party thereby affected elects to be excluded from the application of all of the provisions of Subchapter "K," Chapter 1, Subtitle

51	"A," of the Internal Revenue Code of 1986, as amended ("Code"), as permitted and authorized by Section 761 of the Code and

52	the regulations promulgated thereunder. Operator is authorized and directed to execute on behalf of each party hereby affected

53	such evidence of this election as may be required by the Secretary of the Treasury of the United States or the Federal Internal

54	Revenue Service, including specifically, but not by way of limitation, all of the returns, statements, and the data required by

55	Treasury Regulation §1.761. Should there be any requirement that each party hereby affected give further evidence of this

56	election, each such party shall execute such documents and furnish such other evidence as may be required by the Federal Internal

57	Revenue Service or as may be necessary to evidence this election. No such party shall give any notices or take any other action

58	inconsistent with the election made hereby. If any present or future income tax laws of the state or states in which the Contract

59	Area is located or any future income tax laws of the United States contain provisions similar to those in Subchapter "K," Chapter

60	1, Subtitle "A," of the Code, under which an election similar to that provided by Section 761 of the Code is permitted, each party

61	hereby affected shall make such election as may be permitted or required by such laws. In making the foregoing election, each

62	such party states that the income derived by such party from operations hereunder can be adequately determined without the

63	computation of partnership taxable income.

64	ARTICLE X.

65	CLAIMS AND LAWSUITS

66	Operator may settle any single uninsured third party damage claim or suit arising from operations hereunder if the expenditure

67	does not exceed Fifty thousand Dollars ($ 50,000.00) and if the payment is in complete settlement

68	of such claim or suit. If the amount required for settlement exceeds the above amount, the parties hereto shall assume and take over

69	the further handling of the claim or suit, unless such authority is delegated to Operator. All costs and expenses of handling settling,

70	or otherwise discharging such claim or suit shall be a the joint expense of the parties participating in the operation from which the

71	claim or suit arises. If a claim is made against any party or if any party is sued on account of any matter arising from operations

72	hereunder over which such individual has no control because of the rights given Operator by this agreement, such party shall

73	immediately notify all other parties, and the claim or suit shall be treated as any other claim or suit involving operations hereunder. 74

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	ARTICLE XI.

2	FORCE MAJEURE

3	If any party is rendered unable, wholly or in part, by force majeure to carry out its obligations under this agreement, other

4	than the obligation to indemnify or make money payments or furnish security, that party shall give to all other parties

5	prompt written notice of the force majeure with reasonably full particulars concerning it; thereupon, the obligations of the

6	party giving the notice, so far as they are affected by the force majeure, shall be suspended during, but no longer than, the

7	continuance of the force majeure. The term "force majeure," as here employed, shall mean an act of God, strike, lockout, or

8	other industrial disturbance, act of the public enemy, war, blockade, public riot, lightening, fire, storm, flood or other act of

9	nature, explosion, governmental action, governmental delay, restraint or inaction, unavailability of equipment, and any other

10	cause, whether of the kind specifically enumerated above or otherwise, which is not reasonably within the control of the party

11	claiming suspension.

12	The affected party shall use all reasonable diligence to remove the force majeure situation as quickly as practicable. The

13	requirement that any force majeure shall be remedied with all reasonable dispatch shall not require the settlement of strikes,

14	lockouts, or other labor difficulty by the party involved, contrary to its wishes; how all such difficulties shall be handled shall

15	be entirely within the discretion of the party concerned.

16	ARTICLE XII.

NOTICES

18	All notices authorized or required between the parties by any of the provisions of this agreement, unless otherwise

19	specifically provided, shall be in writing and delivered in person or by United States mail, courier service, telegram, telex,

20	telecopier or any other form of facsimile, postage or charges prepaid, and addressed to such parties at the addresses listed on

21	Exhibit "A." All telephone or oral notices permitted by this agreement shall be confirmed immediately thereafter by written

22	notice. The originating notice given under any provision hereof shall be deemed delivered only when received by the party to

23	whom such notice is directed, and the time for such party to deliver any notice in response thereto shall run from the date

24	the originating notice is received. "Receipt" for purposes of this agreement with respect to written notice delivered hereunder

25	shall be actual delivery of the notice to the address of the party to be notified specified in accordance with this agreement, or

26	to the telecopy, facsimile or telex machine of such party. The second or any responsive notice shall be deemed delivered when

27	deposited in the United States mail or at the office of the courier or telegraph service, or upon transmittal by telex, telecopy

28	or facsimile, or when personally delivered to the party to be notified, provided, that when response is required within 24 or

29	48 hours, such response shall be given orally or by telephone, telex, telecopy or other facsimile within such period. Each party

30	shall have the right to change its address at any time, and from time to time, by giving written notice thereof to all other

31	parties. If a party is not available to receive notice orally or by telephone when a party attempts to deliver a notice required

32	to be delivered within 24 or 48 hours, the notice may be delivered in writing by any other method specified herein and shall

33	be deemed delivered in the same manner provided above for any responsive notice.

34	ARTICLE XIII.

35	TERM OF AGREEMENT

36	This agreement shall remain in full force and effect as to the Oil and Gas Leases and/or Oil and Gas Interests subject

37	hereto for the period of time selected below; provided, however, no party hereto shall ever be construed as having any right, title

38	or interest in or to any Lease or Oil and Gas Interest contributed by any other party beyond the term of this agreement.

39	o Option No. 1: So long as any of the Oil and Gas Leases subject to this agreement remain or are continued in

40	force as to any part of the Contract Area, whether by production, extension, renewal or otherwise.

41	þ Option No. 2: In the event the well described in Article VI.A., or any subsequent well drilled under any provision

42	of this agreement, results in the Completion of a well as a well capable of production of Oil and/or Gas in paying

43	quantities, this agreement shall continue in force so long as any such well is capable of production, and for an

44	additional period of 90 days thereafter; provided, however, if, prior to the expiration of such

45	additional period, one or more of the parties hereto are engaged in drilling, Reworking, Deepening, Sidetracking,

46	Plugging Back, testing or attempting to Complete or Re-complete a well or wells hereunder, this agreement shall

47	continue in force until such operations have been completed and if production results therefrom, this agreement

48	shall continue in force as provided herein. In the event the well described in Article VI.A., or any subsequent well

49	drilled hereunder, results in a dry hole, and no other well is capable of producing Oil and/or Gas from the

50	Contract Area, this agreement shall terminate unless drilling, Deepening, Sidetracking, Completing, Re-

51	completing, Plugging Back or Reworking operations are commenced within _______days from the

52	date of abandonment of said well. "Abandonment" for such purposes shall mean either (i) a decision by all parties

53	not to conduct any further operations on the well or (ii) the elapse of 180 days from the conduct of any

54	operations on the well, whichever first occurs.

55	The termination of this agreement shall not relieve any party hereto from any expense, liability or other obligation or any

56	remedy therefor which has accrued or attached prior to the date of such termination.

57	Upon termination of this agreement and the satisfaction of all obligations hereunder, in the event a memorandum of this

58	Operating Agreement has been filed of record, Operator is authorized to file of record in all necessary recording offices a

59	notice of termination, and each party hereto agrees to execute such a notice of termination as to Operator's interest, upon

60	request of Operator, if Operator has satisfied all its financial obligations.

61	ARTICLE XIV.

62	COMPLIANCE WITH LAWS AND REGULATIONS

63	A. Laws, Regulations and Orders:

64	This agreement shall be subject to the applicable laws of the state in which the Contract Area is located, to the valid rules,

65	regulations, and orders of any duly constituted regulatory body of said state; and to all other applicable federal, state,

66	and local laws, ordinances, rules, regulations and orders.

67	B. Governing Law:

68	This agreement and all matters pertaining hereto, including but not limited to matters of performance, non-

69	performance, breach, remedies, procedures, rights, duties, and interpretation or construction, shall be governed and

70	determined by the law of the state in which the Contract Area is located. If the Contract Area is in two or more states,

71	the law of the state of Colorado shall govern.

72	C. Regulatory Agencies:

73	Nothing herein contained shall grant, or be construed to grant, Operator the right or authority to waive or release any

74	rights, privileges, or obligations which Non-Operators may have under federal or state laws or under rules, regulations or

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	orders promulgated under such laws in reference to oil, gas and mineral operations, including the location, operation, or

2	production of wells, on tracts offsetting or adjacent to the Contract Area.

3	With respect to the operations hereunder, Non-Operators agree to release Operator from any and all losses, damages,

4	injuries, claims and causes of action arising out of, incident to or resulting directly or indirectly from Operator's interpretation

5	or application of rules, rulings, regulations or orders of the Department of Energy or Federal Energy Regulatory Commission

6	or predecessor or successor agencies to the extent such interpretation or application was made in good faith and does not

7	constitute gross negligence. Each Non-Operator further agrees to reimburse Operator for such Non-Operator's share of

8	production or any refund, fine, levy or other governmental sanction that Operator may be required to pay as a result of such

9	an incorrect interpretation or application, together with interest and penalties thereon owing by Operator as a result of such

10	incorrect interpretation or application.

11	ARTICLE XV.

12	MISCELLANEOUS

13	A. Execution:

14	This agreement shall be binding upon each Non-Operator when this agreement or a counterpart thereof has been

15	executed by such Non-Operator and Operator notwithstanding that this agreement is not then or thereafter executed by all of

16	the parties to which it is tendered or which are listed on Exhibit "A" as owning an interest in the Contract Area or which

17	own, in fact, an interest in the Contract Area. Operator may, however, by written notice to all Non-Operators who have

18	become bound by this agreement as aforesaid, given at any time prior to the actual spud date of the Initial Well but in no

19	event later than five days prior to the date specified in Article VI.A. for commencement of the Initial Well, terminate this

20	agreement if Operator in its sole discretion determines that there is insufficient participation to justify commencement of

21	drilling operations. In the event of such a termination by Operator, all further obligations of the parties hereunder shall cease

22	as of such termination. In the event any Non-Operator has advanced or prepaid any share of drilling or other costs

23	hereunder, all sums so advanced shall be returned to such Non-Operator without interest.In the event Operator proceeds

24	with drilling operations for the Initial Well without the execution hereof by all persons listed on Exhibit "A" as having a

25	current working interest in such well, Operator shall indemnify Non-Operators with respect to all costs incurred for the

26	Initial Well which would have been charged to such person under this agreement if such person had executed the same and

27	Operator shall receive all revenues which would have been received by such person under this agreement if such person had

28	executed the same.

29	B. Successors and Assigns:

30	This agreement shall be binding upon and shall inure to the benefit of the parties hereto and their respective heirs,

31	devisees, legal representatives, successors and assigns, and the terms hereof shall be deemed to run with the Leases or

32	Interests included within the Contract Area.

33	C. Counterparts:

34	This instrument may be executed in any number of counterparts, each of which shall be considered an original for all

purposes.

36	D. Severability:

37	For the purposes of assuming or rejecting this agreement as an executory contract pursuant to federal bankruptcy laws,

38	this agreement shall not be severable, but rather must be assumed or rejected in its entirety, and the failure of any party to

39	this agreement to comply with all of its financial obligations provided herein shall be a material default.

40	ARTICLE XVI.

41	OTHER PROVISIONS

ARTICLE XVI. OTHER PROVISIONS

Notwithstanding the foregoing provisions:

A. When a well which has been authorized under the terms of this Agreement as a vertical well shall have been drilled to the objectives authorized in the AFE ("authorized depth"), and all tests have been completed and the results thereof furnished to the participating parties, and after the Operator has attempted in good faith to reach a mutual agreement with Nion-Operator(s) regarding further operations, but such parties cannot agree upon the sequence and timing of further operations regarding said well, the following proposals shall control in the order enumerated hereafter: (1) a proposal to do additional logging, coring, or testing; (2) a proposal to attempt to complete the well at the authorized depth in the manner set forth in the AFE (i.e., in accordance with the casing, stimulation and other completion programs as set forth in the AFE); (3) a proposal to attempt to complete the well at the authorized depth in a manner different than as set forth in the AFE; (4) a proposal to plug back and attempt to complete the well at a depth shallower than the authorized depth, with priority given to objectives in ascending order up the hole; (5) a proposal to drill the well to a depth below the authorized depth, with priority given to objectives in descending order; (6) a proposal to sidetrack the well to a new target objective for a vertical or deviated hole, with priority given first in ascending order to targets above the authorized depth, and then in descending order to targets below the authorized depth; and (7) a proposal to drill a horizontal well, with priority given first to a lateral drain hole at the authorized depth, and then to objectives in ascending order above the authorized depth, and then to objectives in descending order below the authorized depth.

When a well which has been authorized under the terms of this Agreement as a horizontal well shall have been drilled to the authorized depth, and all tests have been completed and the results thereof furnished to the participating parties, and such parties cannot agree upon the sequence and timing of further operations regarding said well, the following proposals shall control in the order enumerated hereafter: (1) a proposal to do additional logging, coring, or testing; (2) a proposal to attempt to complete the well at the authorized depth in the manner set forth in the AFE (i.e. , in accordance with casing, stimulation and other completion programs set forth in the AFE); (3) a proposal to attempt to complete the well at the authorized depth in a manner different than as set forth in the AFE; (4) a proposal to extend the length of the lateral drain hole for a specified number of feet in the direction it is drilling, with priority given to the shortest additional length proposed by any of the participating parties; (5) a proposal to drill a new lateral drain hole in a different direction at the authorized depth; (6) a proposal to drill a new lateral drain hole at a different depth, with priority given in ascending order to objectives above the authorized depth, and then in descending order to objectives below the authorized depth; (7) a proposal to plug back and attempt to complete the well at a depth shallower than the authorized depth, with priority given to objectives in ascending order up the hole; (8) a proposal to deepen the well below the authorized depth; and (9) a proposal to sidetrack the well to a new target objective, with priority given first in ascending order to objectives above the authorized depth, and then in descending order to objectives below the authorized depth.

In a horizontal well, the Operator shall have the right to cease drilling at any time, for any reason, after it has drilled a well to the objective formation and has drilled laterally for a distance which is at least equal to fifty percent (50%) of the length of the total horizontal displacement (displacement from true vertical) proposed for the operation; if in such event the well will be deemed to be at its "authorized depth11 as that term is used in this Agreement.

If at the time the parties are considering a proposed operation, the well is in such condition, in the Operator's judgement, that a reasonably prudent operator would not conduct such operation for fear of mechanical difficulties, placing the hole, equipment or personnel in danger of loss or injury, or fear of loss of the well for any reason without being able to attempt a completion at the authorized depth, then the proposal shall be given no priority to any proposed operation except for plugging and abandoning the well.

B. In the event any Consenting Party desires to deepen a Non-Consent Well to a depth below the authorized depth, such party shall give notice thereof, complying with the requirements of Article Vl.B.I., to all parties (including Non-Consenting Parties). Thereupon Articles Vl.B.1. and 2. shall apply and all parties receiving such notice shall have the right to participate or not participate in the deepening of such well pursuant to said Articles Vl.B.1. and 2 . If a deepening operation is approved pursuant to such provisions, and if any Non-Consenting Party elects to participate in the deepening operation, such Non Consenting Party shall pay or make reimbursement (as the case may be) of the following costs and expenses:

(i)

If the proposal to deepen is made prior to the completion of such well as a well capable of producing in paying quantities, such Non-Consenting Party shall pay (or reimburse Consenting Parties for, as the case may be) that share of costs and expenses incurred in connection with the drilling of said well from the surface to the authorized depth which Non-Consenting Party would have paid had such Non Consenting Party agreed to participate therein, plus the Non-Consenting Party's share of the cost of deepening and of participating in any further operations on the well in accordance with the other provisions of this Agreement; provided, however, all costs for testing and completion or attempted completion of the well incurred by Consenting Parties prior to the point of actual operations to deepen beyond the authorized depth shall be for the sole account of Consenting Parties. Notwithstanding the foregoing, if the Non-Consent well was drilled as a horizontal well, the Non-Consenting Party will be obligated to pay or reimburse the Consenting Parties only that share of the costs and expenses of drilling the vertical portion of the well from the surface to the point that the well is deviated from the vertical.

(ii)

If the proposal is made for a Non-Consent Well that has been previously completed as a well capable of producing in paying quantities, but is no longer capable of producing in paying Quantities, such Non-Consenting Party shall pay (or reimburse Consenting Parties for, as the case may be) its proportionate share of all costs of drilling, completing, and equipping said well from the surface to the authorized depth, calculated in the manner provided in paragraph (i) above, less those costs recouped by the Consenting Parties from the sale of production from the well. The Non-Consenting Party shall also pay its proportionate share of all costs of re entering said well. The Non-Consenting Parties' proportionate part (based on the percentage of such well Non-Consenting Party would have owned had it previously participated in such Non-Consent Well) of the costs of salvable materials and equipment remaining in the hole and salvable surface equipment used in connection with such well shall be determined in accordance with Exhibit "C". If the Consenting Parties have recouped the cost of drilling, completing, and equipping the well at the time such deepening operation is conducted, then a Non-Consenting Party may participate in the deepening of the well with no payment for costs incurred prior to re-entering the well for deepening. Notwithstanding the foregoing, if the Non-Consent well was drilled as a horizontal well, the Non-Consenting Party will be obligated to pay or reimburse the Consenting Parties only that share of the costs and expenses of drilling the vertical portion of the well from the surface to the point that the well is deviated from the vertical.

C. Gas production attributable to any Non-Consenting Party's relinquished interest which was committed to a gas sales contract prior to the date of the relinquishment shall, upon such party's election, be sold to its purchaser, if the purchaser elects to take such production under the terms of its existing gas sales contract. Such Non-Consenting Party shall direct its purchaser to remit the proceeds received from such sale directly to the Consenting Parties until the amounts provided in Article Vl.B.2 are recovered from the Non-Consenting Party's relinquished interest. If such Non-Consenting Party has not contracted for sale of its gas at the time such gas is available for delivery, or does not elect to have its gas delivered to its purchaser as provided above, the Consenting Party shall be entitled to receive and sell such Non-Consenting Party's share of gas during the recoupment period.

D. If operations (including a completion attempt) are necessary to maintain lease acreage which would otherwise expire under the terms of the lease or leases covering such acreage, or are required as a result of a demand for drilling by a lessor, or are necessary to earn leasehold interests or acreage under a farmout or other exploration agreement, the Non-Consent provision shall be changed from that set forth in Article VI to require a non-reversionary assignment of all rights, title, and interest by the party or parties not participating in such operations as to that portion of the acreage (but not any mineral interests owned by a party hereto except to the extent of the lessee's. interest under a lease effected under Article Ill.A hereof) and/or leasehold interest which would otherwise have been lost or not earned without such operations. The provisions of Article VI shall, however, continue to apply to any portion of the Contract Area which is not so jeopardized or not to be earned and which is within the same drilling, production or proration unit. The interests of the parties in said unit shall be adjusted on a surface acreage basis after recovery by the Consenting Parties of the costs to be recouped pursuant to Articles Vl.B (2) (a) and (b) and/or Vll.D (I}, as applicable, with respect to the Non-Consenting Party's interest in the unit subject thereto, and, for avoidance of doubt, the reversion as to such interests not in jeopardy or not to be earned shall occur at the same point in time as such reversion would have occurred absent the forfeiture and assignment. The leasehold interests and oil and gas interests so required to be forfeited and assigned (and the unit, should it contain both forfeiture and reversionary interests) to the Consenting Parties by the Non-Consenting Parties shall no longer be subject to this agreement but shall be subject to an operating agreement) identical to this agreement changed only to reflect the names and new interests of the parties. If operations are proposed on a lease, or on lands pooled therewith, within the last six (6) months of the primary term of a lease not otherwise maintained by other operations or production, such proposed operations will be considered as operations necessary to maintain the lease.

E. If the parties hereto into an agreement between themselves and/or with any third party covering drilling and/or operations on the Contract Area or on other land and leases which are pooled or unitized therewith, then such operating agreement shall supersede this Agreement as to the rights and obligations of the parries with respect to such land and operations. During the term of such other operating agreement, this Agreement shall continue to govern the rights and obligations of the parties as to the balance of the land and depths covered by this Agreement. At such time, if ever, that such other operating agreement shall terminate, or any portion of the Contract Area is released therefrom, then this Agreement shall again become effective as to such land and depths, it being the intent of the parties that there shall never be a time during the term of this Agreement when a portion of the Contract Area is not subject to an operating agreement between the parties hereto.

1	IN WITNESS WHEREOF, this agreement shall be effective as of the ____________________day of__________ ,

2	_____________________.

3	_____________________, who has prepared and circulated this form for execution, represents and warrants that the form was printed from and, with the exception(s) listed below, is identical to the AAPL Form 610-1989 Model Form

4	Operating Agreement, as published in computerized form by Forms On-A-Disk, Inc. No changes, alterations, or modifications, other than those made by strikethrough and/or insertion and that are clearly recognizable as changes in Articles ___________________________, have been made to the form.

6	ATTEST OR WITNESS:		OPERATOR
7			PETROSHARE CORP.
8		By:	/s/ Stephen J. Foley
9			Stephen J. Foley
10			Type or print name
11			Title	CFO
12			Date	11/14/13
13			Tax ID or S.S. No.	46-1454523
14

15	NON-OPERATORS
16
17			LLOLLC, L.L.C.
		By:	/s/ Kemberlia Ducote
18			Kemberlia Ducote
19			Type or print name
20			Title	Manager
21			Date	11/14/13
22			Tax ID or S.S. No.	46-3375198
23

24
25
	By:
26
27		Type or print name
28		Title
29		Date
30		Tax ID or S.S. No.
31

32

	By:
33
34		Type or print name
35		Title
36		Date
37		Tax ID or S.S. No.

A.A.P.I. FORM 610 - MODEL FORM OPERATING AREEMENT - 1989

1	ACKNOWLEDGMENTS

2	Note: The following forms of acknowledgment are the short forms approved by the Uniform Law on Notarial Acts.

3	The validity and effect of these forms in any state will depend upon the statutes of that state.

5	Individual acknowledgment:

6	State of _______________ )

7	State of _______________ ) ss.

8	County of _____________)

9	This instrument was acknowledged before me on

10	_________________________ by _______________________________

12	_________ (Seal, if any) ____________________________________ _______________________________________

13	_________ (Seal, if any)____________________________________Title (and Rank) ___________________________

14	_________ (Seal, if any)____________________________________My commission expires: ___________________________

16	Acknowledgment in representative capacity:

17	State of _______________ )

18	State of _______________ ) ss.

19	County of _____________)

20	This instrument was acknowledged before me on

21	_________________________ by _______________________________ as

22	___________________ of ______________________________________

23	_________ (Seal, if any) ____________________________________ _______________________________________

24	_________ (Seal, if any)____________________________________Title (and Rank) ___________________________

25	_________ (Seal, if any)____________________________________My commission expires: ___________________________

EXHIBIT "A"

Attached to that certain Operating Agreement dated effective_______, 2010, between Quicksilver Resources, Inc., as Operator, and Premier Energy Partners (I) LLC, Buck Peak LLC, and West Point Energy LLC, as Non-Operators.

I.	Oil and Gas Leases Subject to Agreement:

The Oil and Gas Leases more particularly described on Exhibit "A-1" attached hereto.

II.	Participants and Addresses:

	ExpenseInterest
Quicksilver Resources Inc. 777 West Rosedale, Suite 300 Fort Worth, TX 76104 Attn: _________________ Telephone: 817-665-4959 Email: _________________		92.50%

Premier Energy Partners (I) LLC
PO Box 2328 Littleton, CO 80161 Attn: Frederick J. Witsell Telephone: 303-881-2157
Email: ____________

Buck Peak LLC 621 17th Street, Ste.1345 Denver CO 80293 Attn: David Laramie Telephone: 303-573-8600 Email: ____________		7.5%*

West Point Energy LLC
Attn: Gary Semro
Telephone : _____________
Email: __________________

*Non-Operators hereby agree that any election to be made hereunder shall apply to the entire 7.5% interest of Non-Operators. In this connection, Buck Peak LLC and West Point Energy LLC hereby authorize Premier Energy Partners (I) LLC (i) to receive on behalf of Non-Operators all notices called for hereunder, and (ii) to give Operator notice of any election to be made hereunder on behalf of Non-Operators. Non-Operators agree that Operator may rely upon such communications from Premier Energy Partners (I) LLC as binding upon all Non-Operators.

A-1

COPAS 2005 Accounting Procedure

Recommended by COPAS

Exhibit “C”

ACCOUNTING PRODECURE

1		JOINT OPERATIONS
2	Attached to and made part of that certain Operating Agreement dated , 2010, between Quicksilver Resources Inc.
3	as Operator, and Premier Energy Partners (I) LLC, Buck Peak LLC, and West Point Energy LLC, as Non-Operator(s).
4
5
6
7
8		I. GENERAL PROVISIONS
9
10	IF THE PARTIES FAIL TO SELECT EITIIER ONE OF COMPETING "ALTERNATIVE'' PROVISIONS, OR SELECT ALL THE
11	COMPETING "ALTERNATIVE" PROVISIONS, ALTERNATIVE 1IN EACH SUCH INSTANCE SHALL BE DEEMED TO HAVE
12	BEEN ADOPTED BY THE PARTIES AS A RESULT OF ANY SUCH OMISSION OR DUPLICATE NOTATION.
13
14	IN THE EVENT THAT ANY "OPTIONAV' PROVISION OF TIIIS ACCOUNTING PROCEDURE IS NOT ADOPTED BY THE
15	PARTIES TO THE AGREEMENT BY A TYPED, PRINTED OR HANDWRITTEN INDICATION, SUCH PROVISION SHALL NOT
16	FORM A PART OF TIDS ACCOUNTING PROCEDURE, AND NO INFERENCE SHALL BE MADE CONCERNING THE INTENT
17	OF THE PARTIES IN SUCH EVENT.
18
19	1.	DEFINITIONS
20
21		All terms used in this Accounting Procedure shall have the following meaning, unless otherwise expressly defined in the Agreement:
22
23		"Affiliate'' means for a person, another person that controls, is controlled by, or is under common control with that person. In this
24		definition, (a) control means the ownership by one person, directly or indirectly, of more than fifty percent (50%) of the voting securities
25		of a corporation or, for other persons, the equivalent ownership interest (such as partnership interests), and (b) "person" means an
26		individual, corporation, partnership, trust, estate, unincorporated organization, association, or other legal entity.
27
28		"Agreement" means the operating agreement, farmout agreement, or other contract between the Parties to which this Accounting
29		Procedure is attached.
30
31		"Controllable Material" means Material that, at the time of acquisition or disposition by the Joint Account, as applicable, is so classified
32		in the Material Classification Manual most recently recommended by the Council of Petroleum Accountants Societies (COPAS).
33
34		"Equalized Freight" means the procedure of charging transportation cost to the Joint Account based upon the distance from the nearest
35		Railway Receiving Point to the property.
36
37		"Excluded Amount" means a specified excluded trucking amount most recently recommended by COPAS.
38
39		"Field Office" means a structure, or portion of a structure, whether a temporary or permanent installation, the primary function of which is
40		to directly serve daily operation and maintenance activities of the Joint Property and which serves as a staging area for directly chargeable
41		field personnel.
42
43		"First Level Supervision" means those employees whose primary function in Joint Operations is the direct oversight of the Operator's
44		field employees and/or contract labor directly employed On-site in a field operating capacity. First Level Supervision functions may
45		include, but are not limited to:
46
47		▪ Responsibility for field employees and contract labor engaged in activities that can include field operations, maintenance,
48		construction, well remedial work, equipment movement and drilling
49		▪ Responsibility for day-to-day direct oversight of rig operations
50		▪ Responsibility for day-to-day direct oversight of construction operations
51		▪ Coordination of job priorities and approval of work procedures
52		▪ Responsibility for optimal resource utilization (equipment, Materials, personnel)
53		▪ Responsibility for meeting production and field operating expense targets
54		▪ Representation of the Parties in local matters involving community, vendors, regulatory agents and landowners, as an incidental
55		part of the supervisor’s operating responsibilities
56		▪ Responsibility for all emergency responses with field staff
57		▪ Responsibility for implementing safety and environmental practices
58		▪ Responsibility for field adherence to company policy
59		▪ Responsibility for employment decisions and performance appraisals for field personnel
60		▪ Oversight of sub-groups for field functions such as electrical, safety, environmental, telecommunications, which may have group
61		or team leaders.
62
63		"Joint Account" means the account showing the charges paid and credits received in the conduct of the Joint Operations that are to be
64		shared by the Parties, but does not include proceeds attributable to hydrocarbons and by-products produced under the Agreement.
65
66		"Joint Operations" means all operations necessary or proper for the exploration, appraisal, development, production, protection, maintenance, repair, abandonment, and restoration of the Joint Property.

COPAS 2005 Accounting Procedure

Recommended by COPAS

1		"Joint Property" means the real and personal property subject to the Agreement.
2
3		"Laws" means any laws, rules, regulations, decrees, and orders of the United States of America or any state thereof and all other
4		goverenental bodies, agencies, and other authorities having jurisdiction over or affecting the provisions contained in or the transactions
5		contemplated by the Agreement or the Parties and their operations, whether such laws now exist or are hereafter amended, enacted,
6		promulgated or issued.
7
8		"Material" means personal property, equipment, supplies, or consumables acquired or held for use by the Joint Property.
9
10		"Non-Operators" means the Parties to the Agreement other than the Operator.
11
12		"Offshore Facilities" means platforms, surface and subsea development and production systems, and other support systems such as oil and
13		gas handling facilities, living quarters, offices, shops, cranes, electrical supply equipment and systems, fuel and water storage and piping,
14		heliport, marine docking installations, communication facilities, navigation aids, and other similar facilities necessary in the conduct of
15		offshore operations, all of which are located offshore.
16
17		"Off-site" means any location that is not considered On-site as defined in this Accounting Procedure.
18
19		"On-site" means on the Joint Property when in direct conduct of Joint Operations. The term "On-site" shall also include that portion of
20		Offshore Facilities, Shore Base Facilities, fabrication yards, and staging areas from which Joint Operations are conducted, or other
21		facilities that directly control equipment on the Joint Property, regardless of whether such facilities are owned by the Joint Account.
22
23		"Operator" means the Party designated pursuant to the Agreement to conduct the Joint Operations.
24
25		"Parties" means legal entities signatory to the Agreement or their successors and assigns. Parties shall be referred to individually as
26		"Party."
27
28		"Participating Interest" means the percentage of the costs and risks of conducting an operation under the Agreement that a Party agrees,
29		or is otherwise obligated, to pay and bear.
30
31		"Participating Party" means a Party that approves a proposed operation or otherwise agrees, or becomes liable, to pay and bear a share of
32		the costs and risks of conducting an operation under the Agreement.
33
34		"Personal Expenses" means reimbursed costs for travel and temporary living expenses.
35
36		"Railway Receiving Point" means the railhead nearest the Joint Property for which freight rates are published, even though an actual
37		railhead may not exist.
38
39		"Shore Base Facilities" means onshore support facilities that during Joint Operations provide such services to the Joint Property as a
40		receiving and transshipment point for Materials; debarkation point for drilling and production personnel and services; communication,
41		scheduling and dispatching center; and other associated functions serving the Joint Property.
42
43		"Supply Store" means a recognized source or common stock point for a given Material item.
44
45		"Technical Services" means services providing specific engineering, geoscience, or other professional skills, such as those performed by
46		engineers, geologists, geophysicists, and technicians, required to handle specific operating conditions and problems for the benefit of Joint
47		Operations; provided, however, Technical Services shall not include those functions specifically identified as overhead under the second
48		paragraph of the introduction of Section III (Overhead). Technical Services may be provided by the Operator, Operator's Affiliate, Non-
49		Operator, Non-Operator Affiliates, and/or third parties.
50
51	2.	STATEMENTS AND BILLINGS
52
53		The Operator shall bill Non-Operators on or before the last day of the month for their proportionate share of the Joint Account for the
54		preceding month. Such bills shall be accompanied by statements that identify the AFE (authority for expenditure), lease or facility, and all
55		charges and credits summarized by appropriate categories of investment and expense. Controllable Material shall be separately identified
56		and fully described in detail, or at the Operator's option, Controllable Material may be summarized by major Material classifications.
57		Intangible drilling costs, audit adjustments, and unusual charges and credits shall be separately and clearly identified.
58
59		The Operator may make available to Non-Operators any statements and bills required under Section I.2 and/or Section I.3.A (Advances
60		and Payments by the Parties) via email, electronic data interchange, internet websites or other equivalent electronic media in lieu of paper
61		copies. The Operator shall provide the Non-Operators instructions and any necessary information to access and receive the statements and
62		bills within the timeframes specified herein. A statement or billing shall be deemed as delivered twenty-four (24) hours (exclusive of
63		weekends and holidays) after the Operator notifies the Non-Operator that the statement or billing is available on the website and/or sent via
64		email or electronic data interchange transmission. Each Non-Operator individually shall elect to receive statements and billings
65		electronically, if available from the Operator, or request paper copies. Such election may be changed upon thirty (30) days prior written
66		notice to the Operator.

COPAS 2005 Accounting Procedure

Recommended by COPAS

1	3.	ADVANCES AND PAYMENTS BY THE PARTIES
2
3		A. Unless otherwise provided for in the Agreement, the Operator may require the Non-Operators to advance their share of the estimated
4		cash outlay for the succeeding month's operations within fifteen (15) days after receipt of the advance request or by the first day of
5		the month for which the advance is required, whichever is later. The Operator shall adjust each monthly billing to reflect advances
6		received from the Non-Operators for such month. If a refund is due, the Operator shall apply the amount to be refunded to the
7		subsequent month's billing or advance, unless the Non-Operator sends the Operator a written request for a cash refund. The Operator
8		shall remit the refund to the Non-Operator within fifteen (15) days of receipt of such written request.
9
10		B. Except as provided below, each Party shall pay its proportionate share of all bills in full within fifteen (15) days of receipt date. If
11		payment is not made within such time, the unpaid balance shall bear interest compounded monthly at the prime rate published by the
12		Wall Street Journal on the first day of each month the payment is delinquent plus three percent (3%), per annum, or the maximum
13		contract rate permitted by the applicable usury Laws governing the Joint Property, whichever is the lesser, plus attorney's fees, court
14		costs, and other costs in connection with the collection of unpaid amounts. If the Wall Street Journal ceases to be published or
15		discontinues publishing a prime rate, the unpaid balance shall bear interest compounded monthly at the prime rate published by the
16		Federal Reserve plus three percent (3%), per annum. Interest shall begin accruing on the first day of the month in which the payment
17		was due. Payment shall not be reduced or delayed as a result of inquiries or anticipated credits unless the Operator has agreed.
18		Notwithstanding the foregoing, the Non-Operator may reduce payment, provided it furnishes documentation and explanation to the
19		Operator at the time payment is made, to the extent such reduction is caused by:
20
21		(1) being billed at an incorrect working interest or Participating Interest that is higher than such Non-Operator's actual working
22		interest or Participating Interest, as applicable; or
23		(2) being billed for a project or AFE requiring approval of the Parties under the Agreement that the Non-Operator has not approved
24		or is not otherwise obligated to pay under the Agreement; or
25		(3) being billed for a property in which the Non-Operator no longer owns a working interest, provided the Non-Operator has
26		furnished the Operator a copy of the recorded assignment or letter in-lieu. Notwithstanding the foregoing, the Non-Operator
27		shall remain responsible for paying bills attributable to the interest it sold or transferred for any bills rendered during the thirty
28		(30) day period following the Operator's receipt of such written notice; or
29		(4) charges outside the adjustment period, as provided in Section I.4 (Adjustments).
30
31	4.	ADJUSTMENTS
32
33		A. Payment of any such bills shall not prejudice the right of any Party to protest or question the correctness thereof; however, all bills
34		and statements, including payout statements, rendered during any calendar year shall conclusively be presumed to be true and correct,
35		with respect only to expenditures, after twenty-four (24) months following the end of any such calendar year, unless within said
36		period a Party takes specific detailed written exception thereto making a claim for adjustment. The Operator shall provide a response
37		to all written exceptions, whether or not contained in an audit report, within the time periods prescribed in Section I.5 (Expenditure
38		Audits).
39
40		B. All adjustments initiated by the Operator, except those described in items (1) through (4) of this Section I.4.B, are limited to the
41		twenty-four (24) month period following the end of the calendar year in which the original charge appeared or should have appeared
42		on the Operator's Joint Account statement or payout statement. Adjustments that may be made beyond the twenty-four (24) month
43		period are limited to adjustments resulting from the following:
44
45		(1) a physical inventory of Controllable Material as provided for in Section V (Inventories of Controllable Material), or
46		(2) an offsetting entry (whether in whole or in part) that is the direct result of a specific joint interest audit exception granted by the
47		Operator relating to another property, or
48		(3) a government/regulatory audit, or
49		(4) a working interest ownership or Participating Interest adjustment.
50
51	5.	EXPENDITURE AUDITS
52
53		A. A Non-Operator, upon written notice to the Operator and all other Non-Operators, shall have the right to audit the Operator's
54		accounts and records relating to the Joint Account within the twenty-four (24) month period following the end of such calendar year in
55		which such bill was rendered; however, conducting an audit shall not extend the time for the taking of written exception to and the
56		adjustment of accounts as provided for in Section I.4 (Adjustments). Any Party that is subject to payout accounting under the
57		Agreement shall have the right to audit the accounts and records of the Party responsible for preparing the payout statements, or of
58		the Party furnishing information to the Party responsible for preparing payout statements. Audits of payout accounts may include the
59		volumes of hydrocarbons produced and saved and proceeds received for such hydrocarbons as they pertain to payout accounting
60		required under the Agreement. Unless otherwise provided in the Agreement, audits of a payout account shall be conducted within the
61		twenty-four (24) month period following the end of the calendar year in which the payout statement was rendered.
62
63		Where there are two or more Non-Operators, the Non-Operators shall make every reasonable effort to conduct a joint audit in a
64		manner that will result in a minimum of inconvenience to the Operator. The Operator shall bear no portion of the Non-Operators'
65		audit cost incurred under this paragraph unless agreed to by the Operator. The audits shall not be conducted more than once each year
66		without prior approval of the Operator, except upon the resignation or removal of the Operator, and shall be made at the expense of

COPAS 2005 Accounting Procedure

Recommended by COPAS

1		those Non-Operators approving such audit.
2
3		The Non-Operator leading the audit (hereinafter "lead audit company") shall issue the audit report within ninety (90) days after
4		completion of the audit testing and analysis; however, the ninety (90) day time period shall not extend the twenty-four (24) month
5		requirement for taking specific detailed written exception as required in Section I.4.A (Adjustments) above. All claims shall be
6		supported with sufficient documentation.
7
8		A timely filed written exception or audit report containing written exceptions (hereinafter "written exceptions") shall, with respect to
9		the claims made therein, preclude the Operator from asserting a statute of limitations defense against such claims, and the Operator
10		hereby waives its right to assert any statute of limitations defense against such claims for so long as any Non-Operator continues to
11		comply with the deadlines for resolving exceptions provided in this Accounting Procedure. If the Non-Operators fail to comply with
12		the additional deadlines in Section I.5.B or I.5.C, the Operator's waiver of its rights to assert a statute of limitations defense against
13		the claims brought by the Non-Operators shall lapse, and such claims shall then be subject to the applicable statute of limitations,
14		provided that such waiver shall not lapse in the event that the Operator has failed to comply with the deadlines in Section I.5.B or
15		I.5.C.
16
17		B. The Operator shall provide a written response to all exceptions in an audit report within one hundred eighty (180) days after Operator
18		receives such report. Denied exceptions should be accompanied by a substantive response. If the Operator fails to provide substantive
19		response to an exception within this one hundred eighty (180) day period, the Operator will owe interest on that exception or portion
20		thereof, if ultimately granted, from the date it received the audit report. Interest shall be calculated using the rate set forth in Section
21		I.3.B (Advances and Payments by the Parties).
22
23		C. The lead audit company shall reply to the Operator's response to an audit report within ninety (90) days of receipt, and the Operator
24		shall reply to the lead audit company's follow-up response within ninety (90) days of receipt; provided, however, each Non-Operator
25		shall have the right to represent itself if it disagrees with the lead audit company's position or believes the lead audit company is not
26		adequately fulfilling its duties. Unless otherwise provided for in Section I.5.E, if the Operator fails to provide substantive response
27		to an exception within this ninety (90) day period, the Operator will owe interest on that exception or portion thereof, if ultimately
28		granted, from the date it received the audit report. Interest shall be calculated using the rate set forth in Section I.3.B (Advances and
29		Payments by the Parties).
30
31		D. If any Party fails to meet the deadlines in Sections I.5.B or I.5.C or if any audit issues are outstanding fifteen (15) months after
32		Operator receives the audit report, the Operator or any Non-Operator participating in the audit has the right to call a resolution
33		meeting, as set forth in this Section I.5.D or it may invoke the dispute resolution procedures included in the Agreement, if applicable.
34		The meeting will require one month's written notice to the Operator and all Non-Operators participating in the audit. The meeting
35		shall be held at the Operator's office or mutually agreed location, and shall be attended by representatives of the Parties with
36		authority to resolve such outstanding issues. Any Party who fails to attend the resolution meeting shall be bound by any resolution
37		reached at the meeting. The lead audit company will make good faith efforts to coordinate the response and positions of the
38		Non-Operator participants throughout the resolution process; however, each Non-Operator shall have the right to represent itself.
39		Attendees will make good faith efforts to resolve outstanding issues, and each Party will be required to present substantive information
40		supporting its position. A resolution meeting may be held as often as agreed to by the Parties. Issues unresolved at one meeting may
41		be discussed at subsequent meetings until each such issue is resolved.
42
43		If the Agreement contains no dispute resolution procedures and the audit issues cannot be resolved by negotiation, the dispute shall
44		shall choose a mutually acceptable mediator and share the costs of mediation services equally. The Parties shall each have present
45		be submitted to mediation. In such event, promptly following one Party's written request for mediation, the Parties to the dispute
46		at the mediation at least one individual who has the authority to settle the dispute. The Parties shall make reasonable efforts to
47		ensure that the mediation commences within sixty (60) days of the date of the mediation request. Notwithstanding the above, any
48		Party may file a lawsuit or complaint (1) if the Parties are unable after reasonable efforts, to commence mediation within sixty (60)
49		days of the date of the mediation request, (2) for statute of limitations reasons, or (3) to seek a preliminary injunction or other
50		provisional judicial relief, if in its sole judgment an injunction or other provisional relief is necessary to avoid irreparable damage or
51		to preserve the status quo. Despite such action, the Parties shall continue to try to resolve the dispute by mediation.
52
53		E. o (Optional Provision- Forfeiture Penalties)
54		If the Non-Operators fail to meet the deadline in Section I.5.C, any unresolved exceptions that were not addressed by the Non
55		Operators within one (1) year following receipt of the last substantive response of the Operator shall be deemed to have been
56		withdrawn by the Non-Operators. If the Operator fails to meet the deadlines in Section I.5.B or I.5.C, any unresolved exceptions that
57		were not addressed by the Operator within one ( 1) year following receipt of the audit report or receipt of the last substantive response
58		of the Non-Operators, whichever is later, shall be deemed to have been granted by the Operator and adjustments shall be made,
59		without interest, to the Joint Account.
60
61	6.	APPROVAL BY PARTIES
62
63		A. GENERAL MATTERS
64
65		Where an approval or other agreement of the Parties or Non-Operators is expressly required under other Sections of this Accounting
66		Procedure and if the Agreement to which this Accounting Procedure is attached contains no contrary provisions in regard thereto, the

COPAS 2005 Accounting Procedure

Recommended by COPAS

1		Operator shall notify all Non-Operators of the Operator's proposal and the agreement or approval of a majority in interest of the
2		Non-Operators shall be controlling on all Non-Operators.
3
4		This Section I.6.A applies to specific situations of limited duration where a Party proposes to change the accounting for charges from
5		that prescribed in this Accounting Procedure. This provision does not apply to amendments to this Accounting Procedure, which are
6		covered by Section I.6.B.
7
8	B.	AMENDMENTS
9
10		If the Agreement to which this Accounting Procedure is attached contains no contrary provisions in regard thereto, this Accounting
11		Procedure can be amended by an affirmative vote of ___________(__)or more Parties, one of which is the Operator,
12		having a combined working interest of at least___________________percent (___%), which approval shall be binding on all Parties,
13		provided, however, approval of at least one (1) Non-Operator shall be required.
14
15	C.	AFFILIATES
16
17		For the purposes of administering the voting procedures in Section I.6.A and I.6.B, if Parties to this Agreement are Affiliates of each
18		other, then such Affiliates shall be combined and treated as a single Party having the combined working interest or Participating
19		Interest of such Affiliates.
20
21		For the purposes of administering the voting procedures in Section I.6.A, if a Non-Operator is an Affiliate of the Operator, votes
22		under Section I.6.A shall require the majority in interest of the Non-Operator(s) after excluding the interest of the Operator's
23		Affiliate.
24
25		II. DIRECT CHARGES
26
27		The Operator shall charge the Joint Account with the following items:
28
29	1.	RENTALS AND ROYALTIES
30
31		Lease rentals and royalties paid by the Operator, on behalf of all Parties, for the Joint Operations.
32
33	2.	LABOR
34
35		A. Salaries and wages, including incentive compensation programs as set forth in COPAS MFI-37 ("Chargeability of Incentive
36		Compensation Programs"), for
37
38		(1) Operator's field employees directly employed On-site in the conduct of Joint Operations,
39
40		(2) Operator's employees directly employed on Shore Base Facilities, Offshore Facilities, or other facilities serving the Joint
41		Property if such costs are not charged under Section II.6 (Equipment and Facilities Furnished by Operator) or are not a
42		function covered under Section III (Overhead),
43
44		(3) Operator's employees providing First Level Supervision,
45
46		(4) Operator's employees providing On-site Technical Services for the Joint Property if such charges are excluded from the
47		overhead rates in Section III (Overhead),
48
49		(5) Operator's employees providing Off-site Technical Services for the Joint Property if such charges are excluded from the
50		overhead rates in Section III (Overhead).
51
52		Charges for the Operator's employees identified in Section II.2.A may be made based on the employee's actual salaries and wages,
53		or in lieu thereof, a day rate representing the Operator's average salaries and wages of the employee's specific job category.
54
55		Charges for personnel chargeable under this Section II.2.A who are foreign nationals shall not exceed comparable compensation paid
56		to an equivalent U.S. employee pursuant to this Section II.2, unless otherwise approved by the Parties pursuant to Section
57		I.6.A (General Matters).
58
59		B. Operator's cost of holiday, vacation, sickness, and disability benefits, and other customary allowances paid to employees whose
60		salaries and wages are chargeable to the Joint Account under Section II.2.A, excluding severance payments or other termination
61		allowances. Such costs under this Section II.2.B may be charged on a "when and as-paid basis" or by "percentage assessment" on the
62		amount of salaries and wages chargeable to the Joint Account under Section II.2.A. If percentage assessment is used, the rate shall
63		be based on the Operator's cost experience.
64
65		C. Expenditures or contributions made pursuant to assessments imposed by governmental authority that are applicable to costs
66		chargeable to the Joint Account under Sections II.2.A and B

COPAS 2005 Accounting Procedure

Recommended by COPAS

1		D. Personal Expenses of personnel whose salaries and wages are chargeable to the Joint Account under Section II.2.A when the
2		expenses are incurred in connection with directly chargeable activities.
3
4		E. Reasonable relocation costs incurred in transferring to the Joint Property personnel whose salaries and wages are chargeable to the
5		Joint Account under Section 11.2.A. Notwithstanding the foregoing, relocation costs that result from reorganization or merger of a
6		Party, or that are for the primary benefit of the Operator, shall not be chargeable to the Joint Account. Extraordinary relocation
7		costs, such as those incurred as a result of transfers from remote locations, such as Alaska or overseas, shall not be charged to the
8		Joint Account unless approved by the Parties pursuant to Section I.6.A (General Matters).
9
10		F. Training costs as specified in COPAS MFI-35 ("Charging of Training Costs to the Joint Account") for personnel whose salaries and
11		wages are chargeable under Section II.2.A. This training charge shall include the wages, salaries, training course cost, and Personal
12		Expenses incurred during the training session. The training cost shall be charged or allocated to the property or properties directly
13		benefiting from the training. The cost of the training course shall not exceed prevailing commercial rates, where such rates are
14		available.
15
16		G. Operator's current cost of established plans for employee benefits, as described in COPAS MFI-27 ("Employee Benefits Chargeable
17		to Joint Operations and Subject to Percentage Limitation"), applicable to the Operator's labor costs chargeable to the Joint Account
18		under Sections II.2.A and B based on the Operator's actual cost not to exceed the employee benefits limitation percentage most
19		recently recommended by COPAS.
20
21		H. Award payments to employees, in accordance with COPAS MFI-49 ("Awards to Employees and Contractors") for personnel whose
22		salaries and wages are chargeable under Section II.2.A.
23
24	3.	MATERIAL
25
26		Material purchased or furnished by the Operator for use on the Joint Property in the conduct of Joint Operations as provided under Section
27		IV (Material Purchases, Transfers, and Dispositions). Only such Material shall be purchased for or transferred to the Joint Property as
28		may be required for immediate use or is reasonably practical and consistent with efficient and economical operations. The accumulation
29		of surplus stocks shall be avoided.
30
31	4.	TRANSPORTATION
32
33		A. Transportation of the Operator's, Operator's Affiliate's, or contractor's personnel necessary for Joint Operations.
34
35		B. Transportation of Material between the Joint Property and another property, or from the Operator's warehouse or other storage point
36		to the Joint Property, shall be charged to the receiving property using one of the methods listed below. Transportation of Material
37		from the Joint Property to the Operator's warehouse or other storage point shall be paid for by the Joint Property using one of the
38		methods listed below:
39
40		(1) If the actual trucking charge is less than or equal to the Excluded Amount the Operator may charge actual trucking cost or a
41		theoretical charge from the Railway Receiving Point to the Joint Property. The basis for the theoretical charge is the per
42		hundred weight charge plus fuel surcharges from the Railway Receiving Point to the Joint Property. The Operator shall
43		consistently apply the selected alternative.
44
45		(2) If the actual trucking charge is greater than the Excluded Amount the Operator shall charge Equalized Freight. Accessorial
46		charges such as loading and unloading costs, split pick-up costs, detention, call out charges, and permit fees shall be charged
47		directly to the Joint Property and shall not be included when calculating the Equalized Freight.
48
49	5.	SERVICES
50
51		The cost of contract services, equipment, and utilities used in the conduct of Joint Operations, except for contract services, equipment, and
52		utilities covered by Section III (Overhead), or Section II.7 (Affiliates), or excluded under Section II.9 (Legal Expense). Awards paid to
53		contractors shall be chargeable pursuant to COPAS MFl-49 ("Awards to Employees and Contractors").
54
55		The costs of third party Technical Services are chargeable to the extent excluded from the overhead rates under Section III (Overhead).
56
57	6.	EQUIPMENT AND FACILITIES FURNISHED BY OPERATOR
58
59		In the absence of a separately negotiated agreement, equipment and facilities furnished by the Operator will be charged as follows:
60
61		A. The Operator shall charge the Joint Account for use of Operator-owned equipment and facilities, including but not limited to
62		production facilities, Shore Base Facilities, Offshore Facilities, and Field Offices, at rates commensurate with the costs of ownership
63		and operation. The cost of Field Offices shall be chargeable to the extent the Field Offices provide direct service to personnel who
64		are chargeable pursuant to Section II.2.A (Labor). Such rates may include labor, maintenance, repairs, other operating expense,
65		insurance, taxes, depreciation using straight line depreciation method, and interest on gross investment less accumulated depreciation
66		not to exceed _______ percent ( __%) per annum; provided, however, depreciation shall not be charged when the

COPAS 2005 Accounting Procedure

Recommended by COPAS

1		equipment and facilities investment have been fully depreciated. The rate may include an element of the estimated cost for
2		abandonment, reclamation, and dismantlement. Such rates shall not exceed the average commercial rates currently prevailing in the
3		immediate area of the Joint Property.
4
5		B. In lieu of charges in Section II.6.A above, the Operator may elect to use average commercial rates prevailing in the immediate area
6		of the Joint Property, less twenty percent (20%). If equipment and facilities are charged under this Section II.6.B, the Operator shall
7		adequately document and support commercial rates and shall periodically review and update the rate and the supporting
8		documentation. For automotive equipment, the Operator may elect to use rates published by the Petroleum Motor Transport
9		Association (PMTA) or such other organization recognized by COPAS as the official source of rates.
10
11	7.	AFFILIATES
12
13		A. Charges for an Affiliate's goods and/or services used in operations requiring an AFE or other authorization from the Non-Operators
14		may be made without the approval of the Parties provided (i) the Affiliate is identified and the Affiliate goods and services are
15		specifically detailed in the approved AFE or other authorization, and (ii) the total costs for such Affiliate's goods and services billed
16		to such individual project do not exceed $ 500.000.00 If the total costs for an Affiliate's goods and services charged to such
17		individual project are not specifically detailed in the approved AFE or authorization or exceed such amount, charges for such
18		Affiliate shall require approval of the Parties, pursuant to Section I.6.A (General Matters).
19
20		B. For an Affiliate's goods and/or services used in operations not requiring an AFE or other authorization from the Non-Operators,
21		charges for such Affiliate's goods and services shall require approval of the Parties, pursuant to Section I.6.A (General Matters), if the
22		charges exceed $ 500.000.00 in a given calendar year.
23
24		C. The cost of the Affiliate's goods or services shall not exceed average commercial rates prevailing in the area of the Joint Property,
25		unless the Operator obtains the Non-Operators' approval of such rates. The Operator shall adequately document and support
26		commercial rates and shall periodically review and update the rate and the supporting documentation; provided, however,
27		documentation of commercial rates shall not be required if the Operator obtains Non-Operator approval of its Affiliate's rates or
28		charges prior to billing Non-Operators for such Affiliate's goods and services. Notwithstanding the foregoing, direct charges for
29		Affiliate-owned communication facilities or systems shall be made pursuant to Section II.12 (Communications).
30
31		If the Parties fail to designate an amount in Sections II.7.A or II.7.B, in each instance the amount deemed adopted by the Parties as a
32		result of such omission shall be the amount established as the Operator's expenditure limitation in the Agreement. If the Agreement
33		does not contain an Operator's expenditure limitation, the amount deemed adopted by the Parties as a result of such omission shall be
34		zero dollars ($ 0.00).
35
36	8.	DAMAGES AND LOSSES TO JOINT PROPERTY
37
38		All costs or expenses necessary for the repair or replacement of Joint Property resulting from damages or losses incurred, except to the
39		extent such damages or losses result from a Party's or Parties' gross negligence or willful misconduct, in which case such Party or Parties
40		shall be solely liable.
41
42		The Operator shall furnish the Non-Operator written notice of damages or losses incurred as soon as practicable after a report has been
43		received by the Operator.
44
45	9.	LEGAL EXPENSE
46
47		Recording fees and costs of handling, settling, or otherwise discharging litigation, claims, liens and title and regulatory work / incurred in or resulting from
48		operations under the Agreement, or necessary to protect or recover the Joint Property, to the extent permitted under the Agreement. Costs
49		of the Operator's or Affiliate's legal staff or outside attorneys, including fees and expenses, are not chargeable unless approved by the
50		Parties pursuant to Section I.6.A (General Matters) or otherwise provided for in the Agreement.
51
52		Notwithstanding the foregoing paragraph, costs for procuring abstracts, fees paid to outside attorneys for title examinations (including
53		preliminary, supplemental, shut-in royalty opinions, division order title opinions), and curative work shall be chargeable to the extent
54		permitted as a direct charge in the Agreement.
55
56
57	10.	TAXES AND PERMITS
58
59		All taxes and permitting fees of every kind and nature, assessed or levied upon or in connection with the Joint Property, or the production
60		therefrom, and which have been paid by the Operator for the benefit of the Parties, including penalties and interest, except to the extent the
61		penalties and interest result from the Operator's gross negligence or willful misconduct.
62
63		If ad valorem taxes paid by the Operator are based in whole or in part upon separate valuations of each Party's working interest, then
64		notwithstanding any contrary provisions, the charges to the Parties will be made in accordance with the tax value generated by each Party's
65		working interest.
66

COPAS 2005 Accounting Procedure

Recommended by COPAS

1		Costs of tax consultants or advisors, the Operator's employees, or Operator's Affiliate employees in matters regarding ad valorem or other
2		tax matters, are not permitted as direct charges unless approved by the Parties pursuant to Section I.6.A (General Matters).
3
4		Charges to the Joint Account resulting from sales/use tax audits, including extrapolated amounts and penalties and interest, are permitted,
5		provided the Non-Operator shall be allowed to review the invoices and other underlying source documents which served as the basis for
6		tax charges and to determine that the correct amount of taxes were charged to the Joint Account. If the Non-Operator is not permitted to
7		review such documentation, the sales/use tax amount shall not be directly charged unless the Operator can conclusively document the
8		amount owed by the Joint Account.
9
10	11.	INSURANCE
11
12		Net premiums paid for insurance required to be carried for Joint Operations for the protection of the Parties. If Joint Operations are
13		conducted at locations where the Operator acts as self-insurer in regard to its worker's compensation and employer's liability insurance
14		obligation, the Operator shall charge the Joint Account manual rates for the risk assumed in its self-insurance program as regulated by the
15		jurisdiction governing the Joint Property. In the case of offshore operations in federal waters, the manual rates of the adjacent state shall be
16		used for personnel performing work On-site, and such rates shall be adjusted for offshore operations by the U.S. Longshoreman and
17		Harbor Workers (USL&H) or Jones Act surcharge, as appropriate.
18
19	12.	COMMUNICATIONS
20
21		Costs of acquiring, leasing, installing. operating. repairing. and maintaining communication facilities or systems, including satellite, radio
22		and microwave facilities, between the Joint Property and the Operator's office(s) directly responsible for field operations in accordance
23		with the provisions of COPAS MFI-44 ("Field Computer and Communication Systems"). If the communications facilities or systems
24		serving the Joint Property are Operator-owned, charges to the Joint Account shall be made as provided in Section II.6 (Equipment and
25		Facilities Furnished by Operator). If the communication facilities or systems serving the Joint Property are owned by the Operator's
26		Affiliate, charges to the Joint Account shall not exceed average commercial rates prevailing in the area of the Joint Property. The Operator
27		shall adequately document and support commercial rates and shall periodically review and update the rate and the supporting
28		documentation.
29
30	13.	ECOLOGICAL, ENVIRONMENTAL, AND SAFETY
31
32		Costs incurred for Technical Services and drafting to comply with ecological, environmental and safety Laws or standards recommended by
33		Occupational Safety and Health Administration (OSHA) or other regulatory authorities. All other labor and functions incurred for
34		ecological, environmental and safety matters, including management, administration, and permitting, shall be covered by Sections II.2
35		(Labor), II.5 (Services), or Section III (Overhead), as applicable.
36
37		Costs to provide or have available pollution containment and removal equipment plus actual costs of control and cleanup and resulting
38		responsibilities of oil and other spills as well as discharges from permitted outfalls as required by applicable Laws, or other pollution
39		containment and removal equipment deemed appropriate by the Operator for prudent operations, are directly chargeable.
40
41	14.	ABANDONMENT AND RECLAMATION
42
43		Costs incurred for abandonment and reclamation of the Joint Property, including costs required by lease agreements or by Laws.
44
45	15.	OTHER EXPENDITURES
46
47		Any other expenditure not covered or dealt with in the foregoing provisions of this Section II (Direct Charges), or in Section III
48		(Overhead) and which is of direct benefit to the Joint Property and is incurred by the Operator in the necessary and proper conduct of the
49		Joint Operations. Charges made under this Section II.1.5 shall require approval of the Parties, pursuant to Section I.6.A (General Matters).
50
51
52		III. OVERHEAD
53
54		As compensation for costs not specifically identified as chargeable to the Joint Account pursuant to Section II (Direct Charges), the Operator
55		shall charge the Joint Account in accordance with this Section III.
56
57		Functions included in the overhead rates regardless of whether performed by the Operator, Operator's Affiliates or third parties and regardless
58		of location, shall include, but not be limited to, costs and expenses of:
59
60		▪ warehousing, other than for warehouses that are jointly owned under this Agreement
61		▪ design and drafting (except when allowed as a direct charge under Sections II.13, III..I.A.(ii), and III.2, Option B)
62		▪ inventory costs not chargeable under Section V (Inventories of Controllable Material)
63		▪ procurement
64		▪ administration
65		▪ accounting and auditing
66		▪ gas dispatching and gas chart integration

COPAS 2005 Accounting Procedure

Recommended by COPAS

1		▪ human resources
2		▪ management
3		▪ supervision not directly charged under Section II.2 (Labor)
4		▪ legal services not directly chargeable under Section II.9 (Legal Expense)
5		▪ taxation, other than those costs identified as directly chargeable under Section II.10 (Taxes and Permits)
6		▪ preparation and monitoring of permits and certifications; preparing regulatory reports; appearances before or meetings with
7		governmental agencies or other authorities having jurisdiction over the Joint Property, other than On-site inspections; reviewing,
8		interpreting, or submitting contents on or lobbying with respect to Laws or proposed Laws.
9
10		Overhead charges shall include the salaries or wages plus applicable payroll burdens, benefits, and Personal Expenses of personnel performing
11		overhead functions, as well as office and other related expenses of overhead functions.
12
13	1.	OVERHEAD-DRILLING AND PRODUCING OPERATIONS
14
15		As compensation for costs incurred but not chargeable under Section II (Direct Charges) and not covered by other provisions of this
16		Section III, the Operator shall charge on either:
17
18		þ (Alternative 1) Fixed Rate Basis, Section III.1.B.
19		o (Alternative 2) Percentage Basis, Section III.1.C.
20
21	A.	TECHNICAL SERVICES
22
23		(i) Except as otherwise provided in Section II.13 (Ecological Environmental and Safety) and Section III.2 (Overhead - Major
24		Construction and Catastrophe), or by approval of the Parties pursuant to Section I.6.A (General Matters), the salaries, wages,
25		related payroll burdens and benefits, and Personal Expenses for On-site Technical Services, including third party Technical
26		Services:
27
28		þ (Alternative 1- Direct) shall be charged direct to the Joint Account.
29
30		o (Alternative 2 - Overhead) shall be covered by the overhead rates.
31
32		(ii) Except as otherwise provided in Section II.13 (Ecological, Environmental, and Safety) and Section III.2 (Overhead - Major
33		Construction and Catastrophe), or by approval of the Parties pursuant to Section I.6.A (General Matters), the salaries, wages,
34		related payroll burdens and benefits, and Personal Expenses for Off-site Technical Services, including third party Technical
35		Services:
36
37		o (Alternative 1 - All Overhead) shall be covered by the overhead rates.
38
39		o (Alternative 2 - All Direct) shall be charged direct to the Joint Account.
40
41		þ (Alternative 3 - Drilling Direct) shall be charged direct to the Joint Account, only to the extent such Technical Services
42		are directly attributable to drilling, redrilling, deepening, or sidetracking operations, through completion, temporary
43		abandonment, or abandonment if a dry hole. Off-site Technical Services for all other operations, including workover,
44		recompletion, abandonment of producing wells, and the construction or expansion of fixed assets not covered by Section
45		III.2 (Overhead · Major Construction and Catastrophe) shall be covered by the overhead rates.
46
47		Notwithstanding anything to the contrary in this Section III, Technical Services provided by Operator's Affiliates are subject to limitations
48		set forth in Section II.7 (Affiliates). Charges for Technical personnel performing non-technical work shall not be governed by this Section
49		III.1 .A. but instead governed by other provisions of this Accounting Procedure relating to the type of work being performed.
50
51	B.	OVERHEAD-FIXED RATE BASIS
52
53		(1) The Operator shall charge the Joint Account at the following rates per well per month:
54
55		Drilling Well Rate per month $8,200.00 (prorated for less than a full month) / for wells drilled to a TVD of 4,200 feet or more. 5,000.00 for well drilled to a TVD of less than 4,200 feet
56
57		Producing Well Rate per month $820.00 (prorated for less than a full month) / for wells drilled to a TVD of 4,200 feet or more. 500.00 for wells drilled to a TVD of less than 4,200 feet.
58
59		(2) Application of Overhead-Drilling Well Rate shall be as follows:
60
61		(a) Charges for onshore drilling wells shall begin on the date location work begins / and terminate on the date the drilling and/or completion
62		equipment used on the well is released, whichever occurs later. Charges for offshore and inland waters drilling wells shall
63		begin on the date the drilling or completion equipment arrives on location and terminate on the date the drilling or completion
64		equipment moves off location, or is released, whichever occurs first. No charge shall be made during suspension of drilling
65		and/or completion operations for fifteen (15) or more consecutive calendar days.
66

COPAS 2005 Accounting Procedure

Recommended by COPAS

1		(b) Charges for any well undergoing any type of workover, recompletion, and/or abandonment for a period of five (5) or more
2		consecutive work-days shall be made at the Drilling Well Rate. Such charges shall be applied for the period from date
3		operations, with rig or other units used in operations, commence through date of rig or other unit release, except that no charges
4		shall be made during suspension of operations for fifteen (15) or more consecutive calendar days.
5
6		(3) Application of Overhead-Producing Well Rate shall be as follows:
7
8		(a) An active well that is produced, injected into for recovery or disposal, or used to obtain water supply to support operations for
9		any portion of the month shall be considered as a one-well charge for the entire month.
10
11		(b) Each active completion in a multi-completed well shall be considered as a one-well charge provided each completion is
12		considered a separate well by the governing regulatory authority.
13
14		(c) A one-well charge shall be made for the month in which plugging and abandonment operations are completed on any well,
15		unless the Drilling Well Rate applies, as provided in Sections III.1.B.(2)(a) or (b). This one-well charge shall be made whether
16		or not the well has produced.
17
18		(d) An active gas well shut in because of overproduction or failure of a purchaser, processor, or transporter to take production shall
19		be considered as a one-well charge provided the gas well is directly connected to a permanent sales outlet.
20
21		(e) Any well not meeting the criteria set forth in Sections III.1.B.(3) (a), (b), (c), or (d) shall not qualify for a producing overhead
22		charge.
23
24		(4) The well rates shall be adjusted on the first day of April each year following the effective date of the Agreement; provided,
25		however, if this Accounting Procedure is attached to or otherwise governing the payout accounting under a farmout agreement, the
26		rates shall be adjusted on the first day of April each year following the effective date of such farmout agreement. The adjustment
27		shall be computed by applying the adjustment factor most recently published by COPAS. The adjusted rates shall be the initial or
28		amended rates agreed to by the Parties increased or decreased by the adjustment factor described herein, for each year from the
29		effective date of such rates, in accordance with COPAS MFI-47 ("Adjustment of Overhead Rates").
30
31	C.	OVERHEAD-PERCENTAGE BASIS
32
33		(1) Operator shall charge the Joint Account at the following rates:
34
35		(a) Development Rate ______ percent (_____ ) % of the cost of development of the Joint Property, exclusive of costs
36		provided under Section II.9 (Legal Expense) and all Material salvage credits.
37
38		(b) Operating Rate _________percent (_____%) of the cost of operating the Joint Property, exclusive of costs
39		provided under Sections II.1 (Rentals and Royalties) and II.9 (Legal Expense); all Material salvage credits; the value
40		of substances purchased for enhanced recovery; all property and ad valorem taxes, and any other taxes and assessments that
41		are levied, assessed, and paid upon the mineral interest in and to the Joint Property.
42
43		(2) Application of Overhead-Percentage Basis shall be as follows:
44
45		(a) The Development Rate shall be applied to all costs in connection with:
46
47		[i] drilling, redrilling, sidetracking, or deepening of a well
48		[ii] a well undergoing plugback or workover operations for a period of five (5) or more consecutive work-days
49		[iii] preliminary expenditures necessary in preparation for drilling
50		[iv] expenditures incurred in abandoning when the well is not completed as a producer
51		[v] construction or installation of fixed assets, the expansion of fixed assets and any other project clearly discernible as a
52		fixed asset, other than Major Construction or Catastrophe as defined in Section lli.2 (Overhead-Major Construction
53		and Catastrophe).
54
55		(b) The Operating Rate shall be applied to all other costs in connection with Joint Operations, except those subject to Section III.2
56		(Overhead-Major Construction and Catastrophe).
57
58	2.	OVERHEAD-MAJOR CONSTRUCTION AND CATASTROPHE
59
60		To compensate the Operator for overhead costs incurred in connection with a Major Construction project or Catastrophe, the Operator
61		shall either negotiate a rate prior to the beginning of the project, or shall charge the Joint Account for overhead based on the following
62		rates for any Major Construction project in excess of the Operator's expenditure limit under the Agreement, or for any Catastrophe
63		regardless of the amount. If the Agreement to which this Accounting Procedure is attached does not contain an expenditure limit, Major
64		Construction Overhead shall be assessed for any single Major Construction project costing in excess of $100,000 gross.
65
66

COPAS 2005 Accounting Procedure

Recommended by COPAS

1		Major Construction shall mean the construction and installation of fixed assets, the expansion of fixed assets, and any other project clearly
2		discernible as a fixed asset required for the development and operation of the Joint Property, or in the dismantlement, abandonment,
3		removal, and restoration of platforms, production equipment, and other operating facilities.
4
5		Catastrophe is defined as a sudden calamitous event bringing damage, loss, or destruction to property or the environment, such as an oil
6		spill, blowout, explosion, fire, storm, hurricane, or other disaster. The overhead rate shall be applied to those costs necessary to restore the
7		Joint Property to the equivalent condition that existed prior to the event.
8
9		A. If the Operator absorbs the engineering, design and drafting costs related to the project:
10
11		(1) 5.0 % of total costs if such costs are less than $!00,000; plus
12
13		(2) 3.0 % of total costs in excess of $100,000 but less than $1,000,000; plus
14
15		(3) 2.0 % of total costs in excess of $1,000,000.
16
17		B. If the Operator charges engineering, design and drafting costs related to the project directly to the Joint Account:
18
19		(1) 5.0 % of total costs if such costs are less than $!00,000; plus
20
21		(2) 3.0 % of total costs in excess of $100,000 but less than $1,000,000; plus
22
23		(3) 2.0 % of total costs in excess of $1,000,000.
24
25		Total cost shall mean the gross cost of any one project. For the purpose of this paragraph, the component parts of a single Major
26		Construction project shall not be treated separately, and the cost of drilling and workover wells and purchasing and installing pumping
27		units and downhole artificial lift equipment shall be excluded. For Catastrophes, the rates shall be applied to all costs associated with each
28		single occurrence or event.
29
30		On each project, the Operator shall advise the Non-Operator(s) in advance which of the above options shall apply.
31
32		For the purposes of calculating Catastrophe Overhead, the cost of drilling relief wells, substitute wells, or conducting other well operations
33		directly resulting from the catastrophic event shall be included. Expenditures to which these rates apply shall not be reduced by salvage or
34		insurance recoveries. Expenditures that qualify for Major Construction or Catastrophe Overhead shall not qualify for overhead under any
35		other overhead provisions.
36
37		In the event of any conflict between the provisions of this Section III.2 and the provisions of Sections II.2 (Labor), II.5 (Services), or II.7
38		(Affiliates), the provisions of this Section III.2 shall govern.
39
40	3.	AMENDMENT OF OVERHEAD RATES
41
42		The overhead rates provided for in this Section III may be amended from time to time if, in practice, the rates are found to be insufficient
43		Or excessive, in accordance with the provisions of Section I.6.B (Amendments).
44
45
46		IV. MATERIAL PURCHASES, TRANSFERS, AND DISPOSITIONS
47
48		The Operator is responsible for Joint Account Material and shall make proper and timely charges and credits for direct purchases, transfers, and
49		dispositions. The Operator shall provide all Material for use in the conduct of Joint Operations; however, Material may be supplied by the Non-
50		Operators, at the Operator's option. Material furnished by any Party shall be furnished without any express or implied warranties as to quality,
51		fitness for use, or any other matter.
52
53	1.	DIRECT PURCHASES
54
55		Direct purchases shall be charged to the Joint Account at the price paid by the Operator after deduction of all discounts received. The
56		Operator shall make good faith efforts to take discounts offered by suppliers, but shall not be liable for failure to take discounts except to
57		the extent such failure was the result of the Operator's gross negligence or willful misconduct A direct purchase shall be deemed to occur
58		when an agreement is made between an Operator and a third party for the acquisition of Material for a specific well site or location.
59		Material provided by the Operator under "vendor stocking programs," where the initial use is for a Joint Property and title of the Material
60		does not pass from the manufacturer, distributor, or agent until usage, is considered a direct purchase. If Material is found to be defective
61		or is returned to the manufacturer, distributor, or agent for any other reason, credit shall be passed to the Joint Account within sixty (60)
62		days after the Operator has received adjustment from the manufacturer, distributor, or agent.
63
64
65
66

COPAS 2005 Accounting Procedure

Recommended by COPAS

1	2.	TRANSFERS
2
3		A transfer is determined to occur when the Operator (i) furnishes Material from a storage facility or from another operated property, (ii) has
4		assumed liability for the storage costs and changes in value, and (iii) has previously secured and held title to the transferred Material.
5		Similarly, the removal of Material from the Joint Property to a storage facility or to another operated property is also considered a transfer;
6		provided, however, Material that is moved from the Joint Property to a storage location for safe-keeping pending disposition may remain
7		charged to the Joint Account and is not considered a transfer. Material shall be disposed of in accordance with Section IV.3 (Disposition of
8		Surplus) and the Agreement to which this Accounting Procedure is attached.
9
10		A. PRICING
11
12		The value of Material transferred to/from the Joint Property should generally reflect the market value on the date of physical transfer.
13		Regardless of the pricing method used, the Operator shall make available to the Non-Operators sufficient documentation to verify the
14		Material valuation. When higher than specification grade or size tubulars are used in the conduct of Joint Operations, the Operator
15		shall charge the Joint Account at the equivalent price for well design specification tubulars, unless such higher specification grade or
16		sized tubulars are approved by the Parties pursuant to Section l.6.A (General Matters). Transfers of new Material will be priced
17		using one of the following pricing methods; provided, however, the Operator shall use consistent pricing methods, and not alternate
18		between methods for the purpose of choosing the method most favorable to the Operator for a specific transfer:
19
20		(1) Using published prices in effect on date of movement as adjusted by the appropriate COPAS Historical Price Multiplier (HPM)
21		or prices provided by the COPAS Computerized Equipment Pricing System (CEPS).
22
23		(a) For oil country tubulars and line pipe, the published price shall be based upon eastern mill carload base prices (Houston,
24		Texas, for special end) adjusted as of date of movement, plus transportation cost as defined in Section IV.2.B (Freight).
25
26		(b) For other Material, the published price shall be the published list price in effect at date of movement, as listed by a Supply
27		Store nearest the Joint Property where like Material is normally available, or point of manufacture plus transportation
28		costs as defined in Section IV.2.B (Freight).
29
30		(2) Based on a price quotation from a vendor that reflects a current realistic acquisition cost.
31
32		(3) Based on the amount paid by the Operator for like Material in the vicinity of the Joint Property within the previous twelve (12)
33		months from the date of physical transfer.
34
35		(4) As agreed to by the Participating Parties for Material being transferred to the Joint Property, and by the Parties owning the
36		Material for Material being transferred from the Joint Property.
37
38		B. FREIGHT
39
40		Transportation costs shall be added to the Material transfer price using the method prescribed by the COPAS Computerized
41		Equipment Pricing System (CEPS). If not using CEPS, transportation costs shall be calculated as follows:
42
43		(1) Transportation costs for oil country tubulars and line pipe shall be calculated using the distance from eastern mill to the
44		Railway Receiving Point based on the carload weight basis as recommended by the COPAS MFI-38 ("Material Pricing
45		Manual") and other COPAS MFIs in effect at the time of the transfer.
46
47		(2) Transportation costs for special mill items shall be calculated from that mill's shipping point to the Railway Receiving Point.
48		For transportation costs from other than eastern mills, the 30,000-pound interstate truck rate shall be used. Transportation costs
49		for macaroni tubing shall be calculated based on the interstate truck rate per weight of tubing transferred to the Railway
50		Receiving Point.
51
52		(3) Transportation costs for special end tubular goods shall be calculated using the interstate truck rate from Houston, Texas, to the
53		Railway Receiving Point.
54
55		(4) Transportation costs for Material other than that described in Sections IV.2.B.(l) through (3), shall be calculated from the
56		Supply Store or point of manufacture, whichever is appropriate, to the Railway Receiving Point
57
58		Regardless of whether using CEPS or manually calculating transportation costs, transportation costs from the Railway Receiving Point
59		to the Joint Property are in addition to the foregoing, and may be charged to the Joint Account based on actual costs incurred. All
60		transportation costs are subject to Equalized Freight as provided in Section II.4 (Transportation) of this Accounting Procedure.
61
62		C. TAXES
63
64		Sales and use taxes shall be added to the Material transfer price using either the method contained in the COPAS Computerized
65		Equipment Pricing System (CEPS) or the applicable tax rate in effect for the Joint Property at the time and place of transfer. In either
66		case, the Joint Account shall be charged or credited at the rate that would have governed had the Material been a direct purchase.

COPAS 2005 Accounting Procedure

Recommended by COPAS

1	D.	CONDITTON
2
3		(1) Condition "A" - New and unused Material in sound and serviceable condition shall be charged at one hundred percent (100%)
4		of the price as determined in Sections IV.2.A (Pricing), IV.2.B (Freight), and IV.2.C (Taxes). Material transferred from the
5		Joint Property that was not placed in service shall be credited as charged without gain or loss; provided, however, any unused
6		Material that was charged to the Joint Account through a direct purchase will be credited to the Joint Account at the original
7		cost paid less restocking fees charged by the vendor. New and unused Material transferred from the Joint Property may be
8		credited at a price other than the price originally charged to the Joint Account provided such price is approved by the Parties
9		owning such Material, pursuant to Section I.6.A (General Matters). All refurbishing costs required or necessary to return the
10		Material to original condition or to correct handling, transportation, or other damages will be borne by the divesting property.
11		The Joint Account is responsible for Material preparation, handling, and transportation costs for new and unused Material
12		charged to the Joint Property either through a direct purchase or transfer. Any preparation costs incurred, including any internal
13		or external coating and wrapping, will be credited on new Material provided these services were not repeated for such Material
14		for the receiving property.
15
16		(2) Condition "B" - Used Material in sound and serviceable condition and suitable for reuse without reconditioning shall be priced
17		by multiplying the price determined in Sections IV.2.A (Pricing), IV.2.B (Freight), and IV.2.C (Taxes) by seventy-five percent
18		(75%).
19
20		Except as provided in Section IV.2.0(3), all reconditioning costs required to return the Material to Condition "B" or to correct
21		handling, transportation or other damages will be borne by the divesting property.
22
23		If the Material was originally charged to the Joint Account as used Material and placed in service for the Joint Property, the
24		Material will be credited at the price determined in Sections IV.2.A (Pricing), IV.2.B (Freight), and IV.2.C (Taxes) multiplied
25		by sixty-five percent (65%).
26
27		Unless otherwise agreed to by the Parties that paid for such Material, used Material transferred from the Joint Property that was
28		not placed in service on the property shall be credited as charged without gain or loss.
29
30		(3) Condition "C" - Material that is not in sound and serviceable condition and not suitable for its original function until after
31		reconditioning shall be priced by multiplying the price determined in Sections IV.2.A (Pricing), IV.2.B (Freight), and IV.2.C
32		(Taxes) by fifty percent (50%).
33
34		The cost of reconditioning may be charged to the receiving property to the extent Condition "C" value, plus cost of
35		reconditioning, does not exceed Condition "B" value.
36
37		(4) Condition ''D" - Material that (i) is no longer suitable for its original purpose but useable for some other purpose, (ii) is
38		obsolete, or (iii) does not meet original specifications but still has value and can be used in other applications as a substitute for
39		items with different specifications, is considered Condition "D" Material. Casing, tubing, or drill pipe used as line pipe shall be
40		priced as Grade A and B seamless line pipe of comparable size and weight. Used casing, tubing, or drill pipe utilized as line
41		pipe shall be priced at used line pipe prices. Casing, tubing, or drill pipe used as higher pressure service lines than standard line
42		pipe, e.g., power oil lines, shall be priced under normal pricing procedures for casing, tubing, or drill pipe. Upset tubular goods
43		shall be priced on a non-upset basis. For other items, the price used should result in the Joint Account being charged or credited
44		with the value of the service rendered or use of the Material, or as agreed to by the Parties pursuant to Section 1.6.A (General
45		Matters).
46
47		(5) Condition "E" -Junk shall be priced at prevailing scrap value prices.
48
49	E.	OTHER PRICING PROVISIONS
50
51		(1) Preparation Costs
52
53		Subject to Section II (Direct Charges) and Section III (Overhead) of this Accounting Procedure, costs incurred by the Operator
54		in making Material serviceable including inspection, third party surveillance services, and other similar services will be charged
55		to the Joint Account at prices which reflect the Operator's actual costs of the services. Documentation must be provided to the
56		Non-Operators upon request to support the cost of service. New coating and/or wrapping shall be considered a component of
57		the Materials and priced in accordance with Sections IV.l (Direct Purchases) or IV.2.A (Pricing), as applicable. No charges or
58		credits shall be made for used coating or wrapping. Charges and credits for inspections shall be made in accordance with
59		COPAS MFl-38 ("Material Pricing Manual").
60
61		(2) Loading and Unloading Costs
62
63		Loading and unloading costs related to the movement of the Material to the Joint Property shall be charged in accordance with
64		the methods specified in COPAS MFI-38 ("Material Pricing Manual").
65
66

COPAS 2005 Accounting Procedure

Recommended by COPAS

1	3.	DISPOSITION OF SURPLUS
2
3		Surplus Material is that Material, whether new or used, that is no longer required for Joint Operations. The Operator may purchase, but
4		shall be under no obligation to purchase, the interest of the Non-Operators in surplus Material.
5
6		Dispositions for the purpose of this procedure are considered to be the relinquishment of title of the Material from the Joint Property to
7		either a third party, a Non-Operator, or to the Operator. To avoid the accumulation of surplus Material, the Operator should make good
8		faith efforts to dispose of surplus within twelve (12) months through buy/sale agreements, trade, sale to a third party, division in kind, or
9		other dispositions as agreed to by the Parties.
10
11		Disposal of surplus Materials shall be made in accordance with the terms of the Agreement to which this Accounting Procedure is
12		attached. If the Agreement contains no provisions governing disposal of surplus Material, the following terms shall apply:
13
14		▪ The Operator may, through a sale to an unrelated third party or entity, dispose of surplus Material having a gross sale value that
15		is less than or equal to the Operator's expenditure limit as set forth in the Agreement to which this Accounting Procedure is
16		attached without the prior approval of the Parties owning such Material.
17
18		▪ If the gross sale value exceeds the Agreement expenditure limit, the disposal must be agreed to by the Parties owning such
19		Material.
20
21		▪ Operator may purchase surplus Condition "A" or "B" Material without approval of the Parties owning such Material, based on
22		the pricing methods set forth in Section IV.2 (Transfers).
23
24		▪ Operator may purchase Condition "C' Material without prior approval of the Parties owning such Material if the value of the
25		Materials, based on the pricing methods set forth in Section IV.2 (Transfers), is less than or equal to the Operator's expenditure
26		limitation set forth in the Agreement. The Operator shall provide documentation supporting the classification of the Material as
27		Condition C.
28
29		▪ Operator may dispose of Condition "D" or "E" Material under procedures normally utilized by Operator without prior approval
30		of the Parties owning such Material.
31
32	4.	SPECIAL PRICING PROVISIONS
33
34		A. PREMIUM PRICING
35
36		Whenever Material is available only at inflated prices due to national emergencies, strikes, government imposed foreign trade
37		restrictions, or other unusual causes over which the Operator has no control, for direct purchase the Operator may charge the Joint
38		Account for the required Material at the Operator's actual cost incurred in providing such Material, making it suitable for use, and
39		moving it to the Joint Property. Material transferred or disposed of during premium pricing situations shall be valued in accordance
40		with Section IV.2 (Transfers) or Section IV.3 (Disposition of Surplus), as applicable.
41
42		B. SHOP-MADE ITEMS
43
44		Items fabricated by the Operator's employees, or by contract laborers under the direction of the Operator, shall be priced using the
45		value of the Material used to construct the item plus the cost of labor to fabricate the item. If the Material is from the Operator's
46		scrap or junk account, the Material shall be priced at either twenty-five percent (25%) of the current price as determined in Section
47		IV.2.A (Pricing) or scrap value, whichever is higher. In no event shall the amount charged exceed the value of the item
48		commensurate with its use.
49
50		C. MILL REJECTS
51
52		Mill rejects purchased as "limited service" casing or tubing shall be priced at eighty percent (80%) of K-55/J-55 price as determined in
53		Section IV.2 (Transfers). Line pipe converted to casing or tubing with casing or tubing couplings attached shall be priced as K-55/J-
54		55 casing or tubing at the nearest size and weight.
55
56
57		V. INVENTORIES OF CONTROLLABLE MATERIAL
58
59
60		The Operator shall maintain records of Controllable Material charged to the Joint Account, with sufficient detail to perform physical inventories.
61
62		Adjustments to the Joint Account by the Operator resulting from a physical inventory of Controllable Material shall be made within twelve (12)
63		months following the taking of the inventory or receipt of Non-Operator inventory report. Charges and credits for overages or shortages will be
64		valued for the Joint Account in accordance with Section IV.2 (Transfers) and shall be based on the Condition "B" prices in effect on the date of
65		physical inventory unless the inventorying Parties can provide sufficient evidence another Material condition applies.
66

COPAS 2005 Accounting Procedure

Recommended by COPAS

1	1.	DIRECTED INVENTORIES
2
3		Physical inventories shall be performed by the Operator upon written request of a majority in working interests of the Non-Operators
4		(hereinafter, "directed inventory"); provided, however, the Operator shall not be required to perform directed inventories more frequently
5		than once every five (5) years. Directed inventories shall be commenced within one hundred eighty (180) days after the Operator receives
6		written notice that a majority in interest of the Non-Operators has requested the inventory. All Parties shall be governed by the results of
7		any directed inventory.
8
9		Expenses of directed inventories will be borne by the Joint Account; provided, however, costs associated with any post-report follow-up
10		work in settling the inventory will be absorbed by the Party incurring such costs. The Operator is expected to exercise judgment in keeping
11		expenses within reasonable limits. Any anticipated disproportionate or extraordinary costs should be discussed and agreed upon prior to
12		commencement of the inventory. Expenses of directed inventories may include the following:
13
14		A. A per diem rate for each inventory person, representative of actual salaries, wages, and payroll burdens and benefits of the personnel
15		performing the inventory or a rate agreed to by the Parties pursuant to Section I.6.A (General Matters). The per diem rate shall also
16		be applied to a reasonable number of days for pre-inventory work and report preparation.
17
18		B. Actual transportation costs and Personal Expenses for the inventory team
19
20		C. Reasonable charges for report preparation and distribution to the Non-Operators.
21
22	2.	NON-DIRECTED INVENTORIES
23
24		A. OPERATOR INVENTORIES
25
26		Physical inventories that are not requested by the Non-Operators may be performed by the Operator, at the Operator's discretion. The
27		expenses of conducting such Operator-initiated inventories shall not be charged to the Joint Account.
28
29		B. NON-OPERATOR INVENTORIES
30
31		Subject to the terms of the Agreement to which this Accounting Procedure is attached, the Non-Operators may conduct a physical
32		inventory at reasonable times at their sole cost and risk after giving the Operator at least ninety (90) days prior written notice. The
33		Non-Operator inventory report shall be furnished to the Operator in writing within ninety (90) days of completing the inventory
34		fieldwork.
35
36		C. SPECIAL INVENTORIES
37
38		The expense of conducting inventories other than those described in Sections V.1 (Directed Inventories), V.2.A (Operator
39		Inventories), or V.2.B (Non-Operator Inventories), shall be charged to the Party requesting such inventory; provided, however,
40		inventories required due to a change of Operator shall be charged to the Joint Account in the same manner as described in Section
41		V.1 (Directed Inventories).
42
43
44
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63
64
65
66

EXHIBIT "D"

Attached to and made a part of that certain Operating Agreement dated effective ____________ , 2010, by and between Quicksilver Resources, Inc., as Operator, and Premier Energy Partners (I) LLC, Buck Peak LLC, and West Point Energy LLC, as Non-Operators.

INSURANCE

As to all operations hereunder, Operator shall carry for the benefit and protection of the parties hereto the following insurance coverage:

(i) Worker's Compensation or Employer's Liability Insurance as required by the laws of the states in which the operations are conducted.

(ii) Comprehensive General Liability Insurance, including contractual liability, with a combined single limit per occurrence of not less than $1,000,000 for bodily injury and property damage.

(iii) Comprehensive Automobile Insurance, including hired and non-owned vehicles, with a combined single limit per occurrence of not less than $1,000,000 for bodily injury and property damage.

(iv) Liability Umbrella Insurance (excess of underlying insurance coverage mentioned above) with a combined limit per occurrence coverage of not less than $10,000,000.

The cost of the foregoing insurance coverage shall be charged to the parties pursuant to the Accounting Procedure (Exhibit "C") as follows: item (i) will be included in labor rates, items (ii) and (iv) will be charged to the joint account, and item (iii) is included in mileage rates.

If a Non-Operator wishes to obtain its own insurance coverage for any of the above categories, such party shall provide Operator with a certificate evidencing such coverage. In such event, Operator shall not invoice such party for its share of the cost of that particular coverage. Additionally, all such insurance coverages and all of the insurance coverages described above shall contain a waiver of subrogation in favor of all other parties hereto.

Each party shall be responsible for obtaining its own well control or OEE insurance for its proportionate share of such obligation.

To the extent not covered by the aforementioned insurance, the liability of the parties hereto for damages or claims arising out of illness or personal injury to or death of any person or damage to or destruction or loss of property of any person or entity resulting from operations conducted hereunder shall be borne by the parties hereto in the proportions in which they bear the costs of such operations. Additionally, Operator shall not be liable to Non-Operator for damage to or for loss or destruction ofjointly owned property from operations hereunder, EVEN TO THE EXTENT THAT SUCH DAMAGE, LOSS OR DESTRUCTION IS ALLEGED TO HAVE BEEN CAUSED BY OPERATOR'S NEGLIGENCE, unless such damage, loss, or destruction arises solely out of the gross negligence or willful misconduct of Operator.