Document:

Exhibit 10.2 (Q3 2013)

Specific Terms in this Exhibit have been redacted because confidential treatment for those terms has been requested. The redacted material has been separately filed with the Securities and Exchange Commission, and the terms have been marked at the appropriate place with three asterisks [***]

Exhibit 10.2

FIRST AMENDMENT TO
GAS GATHERING AND PROCESSING AGREEMENT

THIS is the FIRST AMENDMENT (“Amendment”) to the GAS GATHERING AND PROCESSING AGREEMENT, dated effective October 1, 2012 (the “Agreement”), by and between EAGLE ROCK FIELD SERVICES, L.P. (“Gatherer”) and BP AMERICA PRODUCTION COMPANY (“Owner”).  Gatherer and Owner are sometimes hereinafter referred to individually as a (“Party”) and collectively as the (“Parties”).  The terms used in this Amendment will have the same meaning as the same terms used in the Agreement.  

WITNESSETH

WHEREAS, Gatherer and SEMINOLE GAS COMPANY, L.L.C. (“Seminole”) are parties to that certain Compression and Treating Agreement dated October 1, 2005, as amended (the “CTA”);
WHEREAS, Gatherer uses the CTA to provide compression and treating services for Owner’s Gas;

WHEREAS, Gatherer and Owner have agreed to share the costs associated with the CTA, a copy of which is attached to this Amendment as Exhibit “A”, and to provide for additional well dedications by Owner to Gatherer; and

WHEREAS, the Parties now desire to amend the Agreement as stated below effective as of the 1st day of July, 2013.    

NOW THEREFORE, for good and valuable consideration, the receipt and sufficiency of which is acknowledged by the Parties, Gatherer and Owner agree to amend the Agreement as follows:

		
	1.
	Article IX, FEES, Section 9.1 of the Agreement shall be amended by adding the following language to the end of the paragraph:

“Effective July 1, 2013 and continuing for the term of the CTA or a replacement agreement, each Month Gatherer shall charge Owner [***] percent ([***]%) of the fee charged to Gatherer by Seminole pursuant to the CTA ($[***] being the initial [***]% fee) for compression and treating services for Owner’s Gas pursuant to Exhibit “D”.    Notwithstanding the above, Owner shall receive [***]% of any credit received by Gatherer from Seminole where the monthly average compressor performance is less than [***]%.  Gatherer shall allocate these fees to Owner’s gas pursuant to the new Section 10.6, set forth hereinafter.  The Parties agree that any replacement agreement or amendment intended to supersede, modify, or terminate the CTA prior to the end of the primary term of the CTA (being three (3) years)  shall not be effective unless and until Owner provides prior written consent to such replacement agreement or amendment, which consent shall not be unreasonably withheld or delayed.  During the term of the CTA or a replacement agreement or amendment thereof, Gatherer will not exercise any right it may have to terminate that certain Letter Agreement dated October 2, 2002, by and between CMS Energy Field Services (now PVR Natural Gas Gathering L.L.C. (“PVR”)) and BP America Production Company (now Eagle Rock Field Services, L.P.), providing for a lease by Gatherer of PVR’s Natural Gas Gathering System.”

Gatherer agrees to notify Owner of any exceptions related to Seminoles’ compressor performance guarantee pursuant to the CTA within seven (7) days of receiving acknowledgment from Seminole.”

		
	2.
	Article X, ALLOCATION AND DISPOSITION, of the Agreement shall be amended by adding the following Section 10.6 to the Agreement with the following language:

10.6 Gatherer agrees to perform all calculations, allocations, dispositions, and other duties specified in Sections 10.1 through 10.5 for Owner’s Gas dedicated in the amended Section 15.4, set forth hereinafter, back to the Well’s 

Specific Terms in this Exhibit have been redacted because confidential treatment for those terms has been requested. The redacted material has been separately filed with the Securities and Exchange Commission, and the terms have been marked at the appropriate place with three asterisks [***]

wellhead.  Gatherer agrees to allocate the CTA fees pursuant to Section 9.1 of this Amendment in a ratio that the volume of Gas measured in Heating Value from each Well listed on Exhibit D of this Amendment bears to the total volume of gas measured in Heating Value from all Wells  listed on Exhibit D hereto.  Owner agrees to provide, or cause to be provided, all information necessary for Gatherer to perform all calculations, allocations, dispositions, and other duties specified in Sections 10.1 through 10.5.

		
	3.
	Article XV, TERM AND DEDICATION, of the Agreement shall be amended by adding the following Section 15.4 to the Agreement with the following language:

15.4  Owner agrees to dedicate to the performance of this Agreement Gas produced from its current and future Wells connected to the PVR Courson Ranch and Superior Pipeline Texas L.L.C. (“Superior”) Etheredge gathering systems for the term of the CTA or a subsequent replacement agreement.  Gas produced from Wells on the PVR Courson Ranch  shall be delivered to Gatherer via the Reed and/or Mathews delivery points. Gas produced from Wells on the Superior Etheredge gathering system shall be delivered to Gatherer at Gatherer’s Dumler Compressor Station Receipt Point located in Section 23, Block 1, I&GN RR CO Survey, Hemphill County. Refer to Exhibit “B” for a list of dedicated Wells on the PVR Courson Ranch gathering system.  Refer to Exhibit “C” for a list of dedicated Wells on the Superior gathering system.

All other terms of the Agreement, as amended, shall remain in full force and effect.

IN WITNESS WHEREOF, the Parties have executed this Amendment to the Agreement on the dates shown below. 

BP AMERICA PRODUCTION COMPANY        EAGLE ROCK FIELD SERVICES, L.P.
By its general partner, Eagle Rock Pipeline GP, LLC

By:  /s/ David W. Grisko                By:  Roger A. Fox
Name:      David W. Grisko                Name:  R. A. Fox
Title:  Attorney-in-Fact                    Title:  SVP Midstream Business
Date:   8/1/2013                        Date:  7/23/2013
    

Specific Terms in this Exhibit have been redacted because confidential treatment for those terms has been requested. The redacted material has been separately filed with the Securities and Exchange Commission, and the terms have been marked at the appropriate place with three asterisks [***]

Exhibit A
 To
First Amendment to Gas Gathering And Processing Agreement

SECOND AMENDMENT
To 
COMPRESSION AND TREATING AGREEMENT

This Second Amendment to the Compression and Treating Agreement (hereinafter referred to as “Amendment”) is made and entered into as of July 1, 2013, by and between Seminole Gas Company, L.L.C. (hereinafter referred to as “Seminole”) and Eagle Rock Field Services, L.P. (hereinafter referred to as “Eagle Rock”).  Seminole and Eagle Rock may be referred to individually as a “Party” or collectively as the “Parties”.

WHEREAS, Seminole and Eagle Rock (as successor to BP America Production Company, are parties to that certain Compression and Treating Agreement, dated October 1, 2005 (the “Master Agreement”); 

WHERAS, Exhibit A to the Master Agreement was previously amended, commencing effective October 1, 2008 (the “First Amendment”); and

WHEREAS, Seminole and Eagle Rock wish to amend the Master Agreement, as amended, in the manner specified below.

NOW, THEREFORE, in consideration of the mutual covenants herein contained, and other good and valuable consideration, the receipt and sufficiency of which each Party hereby acknowledges, Seminole and Eagle Rock hereby agree to amend the Master Agreement as follows:

		
	1.
	Exhibit “A

The attached Second Amended Exhibit “A” shall hereby replace and supersede Exhibit “A”, as previously amended under the First Amendment, in its entirety.

		
	2.
	Delivery Points

The Parties herby agree that Gas will no longer be compressed and treated under the Master Agreement at the 13-73 Delivery Point. 

		
	3.
	Term

The Parties hereby agree to extend the Term of the Agreement, commencing July 1, 2013, for a period of three (3) years, and year to year thereafter until terminated, such termination to be effective at the end of such three (3) year extension or any year thereafter by either Party giving at least six (6) Months prior written notice to the other Party

		
	4.
	Performance

Seminole hereby guarantees that the services described and to be provided under the Master Agreement and as amended herein will be mechanically available 95% of the time beginning after the first thirty (30) days of operation.  In the event the mechanical availability is less than 95% when averaged over a one (1) month 

Specific Terms in this Exhibit have been redacted because confidential treatment for those terms has been requested. The redacted material has been separately filed with the Securities and Exchange Commission, and the terms have been marked at the appropriate place with three asterisks [***]

period, a penalty will be assessed against Seminole whereby the monthly compression and Treating Fee will be determined by multiplying the normal monthly compression by the percentage of time the equipment was available and dividing that product by 95%.  To be eligible for the penalty described herein, Eagle Rock must make a written request for credit with substantiation of the downtime within thirty (30) days after the period in which this performance guarantee is not met.  Downtime to the extent resulting from the following causes is exempt from this guarantee:

		
	•
	for the convenience of Eagle Rock;

		
	•
	for routine maintenance and inspection, limited to four (4) hours per month per compression unit;

		
	•
	because of the unavailability of gas;

		
	•
	because of free liquids and/or solids in the gas stream

		
	•
	because of high discharge pipeline pressures

		
	•
	because of Eagle Rock negligence;

		
	•
	because of regulatory restrictions imposed on Seminole that arise for changes the gas composition;

		
	•
	because of events outside the control of Seminole  that are not related to the Courson Ranch Facilities;

        
Except as amended or modified by this Second Amendment, the Master Agreement, and each of its terms and provisions, shall remain in full force and effect. 

IN WITNESS WHEREOF, this Second Amendment to Compression and Treating Agreement has been executed by the Parties as of the date first above written.

		
	Seminole Gas Company, L.L.C.
	Eagle Rock Field Services, L.P.

________________________________        ______________________________    

Name:  _________________________        Name:  _______________________
Title:  __________________________        Title:  ________________________

Specific Terms in this Exhibit have been redacted because confidential treatment for those terms has been requested. The redacted material has been separately filed with the Securities and Exchange Commission, and the terms have been marked at the appropriate place with three asterisks [***]

SECOND AMENDED EXHIBIT “A”

TO

COMPRESSION AND TREATING AGREEMENT
Between
Eagle Rock Field Services, L.P.
And
Seminole Gas Company, L.L.C.

Delivery Point

Inlet of the compressor unit located at the 16-65 Delivery point, Section 167, Blk C, H&M Survey, Roberts County, Texas

Maximum Daily Pressures and Volumes

Inlet Pressure     [***] psig          Max Volume - [***] Mcf per day (Seminole East)
Inlet Pressure    [***] psig        Max Volume - [***] Mcf per day (Seminole East)

Minimum Inlet Pressure

Inlet pressure shall never be at a vacuum or measured at the inlet side of Seminole’s compressor.

Maximum Outlet Pressure

Outlet pressure shall be [***] psig as measured at the outlet of Seminole’s treating facility.

Compression and Treating Fee

Seminole will be paid a monthly Compression and Treating Fee commencing on the 1st day of July, 2013, continuing during the Term of this Agreement.  The monthly Compression and Treating Fee will be $[***].  Eagle Rock further agrees to pay for water hauling services from the 16-65 Delivery Point.  The service for the water hauling will be added to the monthly compressor and treating statement billed monthly to Eagle Rock. 

Specific Terms in this Exhibit have been redacted because confidential treatment for those terms has been requested. The redacted material has been separately filed with the Securities and Exchange Commission, and the terms have been marked at the appropriate place with three asterisks [***]

Exhibit B
 To
First Amendment to Gas Gathering And Processing Agreement
Effective July 1, 2013
Dedicated Wells on PVR Courson Ranch Gathering System

	
				
	PVR Meter Number
	BP Meter Number
	Well Name
	Gatherer Receipt Point

	70,134
	 
	Lips B#9
	Reed

	658,314
	5,542
	Kan City Min Roy CO GU/A/2AL
	Mathews

	195,487
	79,120
	McLain Gas Unit #2
	Mathews

	70,003
	80,237
	Brainard Unit #3
	Mathews

	195,464
	70,726
	Mathews Unit #2
	Mathews

	195,482
	76,833
	Mathews Unit #3
	Mathews

	70,022
	310,585
	Brainard, E.S.F. #3
	Mathews

	70,035
	311,267
	Mathews 2 - #1
	Mathews

	195,350
	22
	Austin Unit #2
	Reed

	195,082
	650
	Jarvis, Raymond #1
	Mathews

	195,436
	65,133
	Austin Unit #3
	Reed

	195,477
	74,528
	Jarvis, Raymond #2
	Mathews

	195,488
	78,829
	Beck Unit /B/#4
	Mathews

	195,497
	78,902
	Jarvis, Raymond #3
	Mathews

	70,001
	80,091
	Austin Unit #4
	Reed

	195,344
	320
	Pearson Unit /F/#2
	Mathews

	195,076
	490
	Pearson Unit /D/#1
	Mathews

	195,123
	4,690
	Pearson Unit /F/#1
	Mathews

	70,007
	310,580
	Crumb, Nadine #1
	Reed

	195,372
	126
	Lips Ranch /B/#26
	Reed

	195,418
	140
	Courson /B/13
	Reed

	195,044
	322
	Lips Ranch /B/#1
	Reed

	195,081
	4,700
	Lips Ranch /B/#15
	Reed

	195,099
	5,009
	Lips Ranch /B/#11
	Reed

	195,420
	49,872
	Lips Ranch /B/#11-31
	Reed

	195,439
	49,876
	Lips Ranch /B/#15-35
	Reed

	195,423
	65,463
	Lips Ranch /B/#15-32
	Reed

	195,467
	71,203
	Lips Ranch /B/#11-48
	Reed

	195,472
	72,253
	Lips Ranch /B/#13-47
	Reed

	70,041
	312,375
	Courson /B/#13-64
	Reed

	658,310
	3,932
	Lips Ranch /B/#8
	Reed

	195,486
	77,867
	Lips Ranch /B/#8-49
	Reed

	195,109
	132
	Lips Ranch /B/#19
	Reed

	195,080
	134
	Lips Ranch /B/#17
	Reed

	195,411
	138
	Lips Ranch /B/#14
	Reed

	658,313
	3,934
	Lips Ranch /B/#25
	Reed

	195,337
	3,960
	Lips Ranch /B/#17-23
	Reed

	195,424
	49,483
	Lips Ranch /B/#8-36
	Reed

	195,446
	65,458
	Lips Ranch /B/#14-40
	Reed

Specific Terms in this Exhibit have been redacted because confidential treatment for those terms has been requested. The redacted material has been separately filed with the Securities and Exchange Commission, and the terms have been marked at the appropriate place with three asterisks [***]

	
				
	195,484
	77,644
	Lips Ranch /B/#19-59
	Reed

	195,485
	77,760
	Lips Ranch /B/#17-53 (COMM.)
	Reed

	70,008
	81,689
	Brainard, E.S.F. #1
	Mathews

	70,011
	82,199
	Courson /D/#2-157
	Reed

	70,020
	87,859
	Courson /D/#2-170
	Mathews

	70,026
	308,509
	Brainard, E.S.F. #5 UT
	Mathews

	70,030
	309,991
	Courson /D/#1-172
	Reed

	195,419
	146
	Lips Ranch /B/#3
	Reed

	195,412
	148
	Courson B #4
	Reed

	195,431
	48,370
	Lips Ranch /B/#4-33 L
	Reed

	195,440
	48,939
	Lips Ranch /B/#3-39
	Reed

	195,421
	48,966
	Lips Ranch /B/#4-37
	Reed

	195,438
	65,445
	Lips Ranch /B/#12-38
	Reed

	195,454
	67,480
	Lips Ranch /B/#1-41 L
	Reed

	195,457
	67,495
	Lips Ranch /B/#3-43 L
	Reed

	195,468
	73,003
	Courson B 4-52
	Reed

	195,490
	78,466
	Lips Ranch /B/#4-60
	Reed

	70,033
	310,579
	Brainard #4-4
	Reed

	195,096
	324
	McIntire, W B, /B/ #1
	Reed

	195,422
	65,473
	McIntire, W B, /B/ #2
	Reed

	195,432
	65,476
	McIntire, W B, /B/ #3
	Reed

	195,078
	142
	Lips Ranch /B/ #12
	Reed

	658,440
	48,636
	Lips Ranch /B/ #9-30
	Reed

	70,004
	80,782
	Courson /C/ #1 (Morrow)
	Mathews

	70,017
	85,841
	Courson /C/ #2
	Mathews

	35,052
	735
	Mathews Unit #1
	Mathews

	35,061
	667
	Beck Unit /B/#1
	Mathews

	52,240
	100
	McIntire, W B, /A/15#2
	Reed

Specific Terms in this Exhibit have been redacted because confidential treatment for those terms has been requested. The redacted material has been separately filed with the Securities and Exchange Commission, and the terms have been marked at the appropriate place with three asterisks [***]

Exhibit C
 To
First Amendment to Gas Gathering And Processing Agreement
Effective July 1, 2013
Dedicated Wells on Superior Etheredge Gathering System

	
				
	Meter Number
	Well Name
	Owner Working Interest
	Gatherer Receipt Point

	77,895
	Etheredge Gas Unit #1
	87.500014%
	Dumler Compressor Station

	77,897
	Etheredge Gas Unit #2
	87.500014%
	Dumler Compressor Station

	77,898
	Etheredge Gas Unit #3
	87.500054%
	Dumler Compressor Station

	77,899
	Etheredge Gas Unit #4
	87.500054%
	Dumler Compressor Station

	77,900
	Etheredge Gas Unit #5L
	87.500054%
	Dumler Compressor Station

	78,015
	Etheredge Gas Unit #5U
	87.500054%
	Dumler Compressor Station

	77,901
	Etheredge Gas Unit #6L
	87.500014%
	Dumler Compressor Station

	78,016
	Etheredge B 6U
	87.5%
	Dumler Compressor Station

	77,903
	Etheredge Gas Unit #7L
	87.500014%
	Dumler Compressor Station

	77,902
	Etheredge Gas Unit #7U
	87.500014%
	Dumler Compressor Station

	77,904
	Etheredge Gas Unit #8
	87.500014%
	Dumler Compressor Station

Specific Terms in this Exhibit have been redacted because confidential treatment for those terms has been requested. The redacted material has been separately filed with the Securities and Exchange Commission, and the terms have been marked at the appropriate place with three asterisks [***]

Exhibit D
 To
First Amendment to Gas Gathering And Processing Agreement
Effective July 1, 2013
Dedicated Wells on PVR Natural Gas Gathering System
	
		
	Meter Number
	Well Name

	313,295
	Courson B-13-73

	313,613
	Courson B-16-79

	313,618
	Courson B-3-71

	313,625
	Courson B-16-65

	313,627
	Courson B-5-77

	313,641
	Courson B-5-76

	313,653
	Courson B-5-78

	313,012
	Courson D-22-2

	667
	Beck B-46-1

	420,204
	Courson B 9

	310,893
	Courson B-14-61

	313,615
	Courson B-16-44

	313,616
	Courson B-5-45

	313,620
	Courson B-22

	313,621
	Courson B-21

	313,622
	Courson B-5-29

	313,623
	Courson B-14-34

	313,624
	Courson B-28Exhibit 10.3 (Q3 2013)

Specific Terms in this Exhibit have been redacted because confidential treatment for those terms has been requested. The redacted material has been separately filed with the Securities and Exchange Commission, and the terms have been marked at the appropriate place with three asterisks [***]

Exhibit 10.3

SECOND AMENDMENT TO
GAS GATHERING AND PROCESSING AGREEMENT

THIS SECOND AMENDMENT TO GAS GATHERING AND PROCESSING AGREEMENT, dated effective July 1, 2013 (this “Amendment”), is by and between EAGLE ROCK FIELD SERVICES, L.P. (“Gatherer”) and BP AMERICA PRODUCTION COMPANY (“Owner”).  Gatherer and Owner are sometimes hereinafter referred to individually as a (“Party”) and collectively as the (“Parties”).  The terms used in this Amendment will have the same meaning as the same terms used in the Agreement.  
WITNESSETH

WHEREAS, Gatherer and Owner are parties to that certain Gas Gathering and Processing Agreement dated effective October 1, 2012 (as amended, the “Agreement”); 
WHEREAS, pursuant to Article VI of the Agreement, the Maximum Allowable Pressures, from the Effective Date through the third anniversary of the Effective Date, are to be set by good faith commercially reasonable efforts;
WHEREAS, Gatherer and Owner, in accordance with Article VI of the Agreement, have agreed upon such Maximum Allowable Pressures;

WHEREAS, the Parties now desire to amend the Agreement as stated below.    

NOW THEREFORE, for good and valuable consideration, the receipt and sufficiency of which is acknowledged by the Parties, Gatherer and Owner agree to amend the Agreement as follows:

		
	1.
	Article VI, RECEIPT PRESSURE, Section 6.2, “Maximum Allowable Pressures” table shall be deleted and replaced with the table attached hereto as Exhibit “A.”

		
	2.
	Article VI, Receipt Pressure, Section 6.3 of the Agreement shall be deleted and replaced with the following language:

6.3    For all Sections in the Sweet Gas System not specifically designated in Exhibit B to the Table in Section 6.2 (collectively, the “Sweet Gas Area”), the Monthly average operating Gathering System pressure shall be calculated as a simple average each Month considering only Receipt Points of Wells with first Gas within the prior one hundred and twenty (120) Months to the calculation Month, without weighting for volume, but shall exclude Wells within Areas listed in the Table above.  For the Sweet Gas Area, the Maximum Allowable Pressure shall be:  (i) as of July 1, 2013 through the 3rd anniversary of the Effective Date, (a) [***] psig for all of East Lipscomb County east of Highway 305, (b) [***] psig for all of Ochiltree County, and (c) [***] psig for the remaining Sweet Gas Area; and then (ii) as of the 3rd anniversary of the Effective Date through end of the Agreement, [***] psig.  

		
	3.
	Article VI, Receipt Pressure, Sections 6.4(a) of the Agreement shall be deleted and replaced with the following language:

a.    that tie into the Sherman Gathering System which are substantially located in Sherman County (the “Sherman Sour Gas Area”).  For the Sherman Sour Gas Area the Maximum Allowable Pressure shall be:  (i) as of July 1, 2013 through the 3rd anniversary of the Effective Date, [***] psig; and then (ii) as of the 3rd anniversary of the Effective Date through end of the Agreement, [***] psig; and

		
	4.
	Article VI, Receipt Pressure, Sections 6.4(b) of the Agreement shall be deleted and replaced with the following language:

Specific Terms in this Exhibit have been redacted because confidential treatment for those terms has been requested. The redacted material has been separately filed with the Securities and Exchange Commission, and the terms have been marked at the appropriate place with three asterisks [***]

b.    that tie into the Moore Gathering System which are substantially located in Moore County (the “Moore Sour Gas Area”).  For the Moore Sour Gas Area the Maximum Allowable Pressure shall be: (i) as of July 1, 2013 through the 3rd anniversary of the Effective Date, [***] psig; and then (ii) as of the 3rd anniversary of the Effective Date through end of the Agreement, [***] psig.  

All other terms of the Agreement, as amended, shall remain in full force and effect.

IN WITNESS WHEREOF, the Parties have executed this Amendment to the Agreement on the dates shown below. 

BP AMERICA PRODUCTION COMPANY        EAGLE ROCK FIELD SERVICES, L.P.
By its general partner, Eagle Rock Pipeline GP, LLC

By:   /s/ David W. Grisko                By:  /s/ Roger Fox
Name:   David W. Grisko                Name: Roger Fox
Title:  Attorney-in-Fact                    Title:  Sr. VP - Midstream Business
Date: 8/20/2013                        Date:  8/27/2013
    

Specific Terms in this Exhibit have been redacted because confidential treatment for those terms has been requested. The redacted material has been separately filed with the Securities and Exchange Commission, and the terms have been marked at the appropriate place with three asterisks [***]

Exhibit A
 To
Second Amendment to Gas Gathering And Processing Agreement
Effective July 1, 2013
MAXIMUM ALLOWABLE PRESSURES
	
					
	Area
	County (in general)
	Description (specific sections are In Exhibit “B”)
	As of Effective Date through 3rd anniversary of Effective Date
	As of 3rd anniversary of Effective Date through end of the Agreement

	West Chambers 1
	Roberts
	Sections East of Clark Compressor Station encompassing 10” suction line
	[***] psig
	[***] psig

	West Chambers 2
	Roberts
	Sections West of Chambers Compressor Station
	[***] psig
	[***] psig

	East Chambers 1
	Roberts
	Sections East of Chambers Compressor Station, includes Superior Mendota Offload
	[***] psig
	[***] psig

	East Chambers 2
	Roberts
	Sections West of Isaacs Compressor Station Site
	[***] psig
	[***] psig

	NE Chambers 1
	Primarily Hemphill
	Sections with offload capa1city (Eagle Rock and Superior) near header North of Isaacs Compressor Station Site
	[***] psig
	[***] psig

	NE Chambers 2
	Primarily Hemphill
	Sections immediately North and Northwest of Issacs Compressor Station Site
	[***] psig
	[***] psig

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