Columbia Gulf Transmission, LLC FERC NGA Gas Tariff Baseline Tariffs Proposed Effective Date: March 14, 2018 Service Agreement No.

Transcription

1 Columbia Gulf Transmission, LLC FERC NGA Gas Tariff Baseline Tariffs Proposed Effective Date: March 14, 2018 Service Agreement No Marubeni Natural Gas and LNG America Corp. Option Code A

2 Service Agreement No Revision No. 0 FTS-1 SERVICE AGREEMENT THIS FTS-1 SERVICE AGREEMENT is made and entered into this lst day of July, 2016 (this "Agreement"), by and between COLUMBIA GULF TRANSMISSION, LLC ("Transporter") and MARUBENI NATURAL GAS AND LNG AMERICA CORP. ("Shipper"), Transporter and Shipper may be referred to herein individually as a "Party'' and collectively as the "Parties." WIT NE S S ET H: \ivhereas, Transporter is a provider of natural gas transportation services subject to the jurisdiction of the Federal Energy Regulatory Commission ("FERC'' or "Commission"); and WHEREAS, Shipper desires to subscribe for firm natural gas transportation service from Transporter pursuant to Transporter's FERC approved Rate Schedule FTS-1 ("FTS-1 ") and the Columbia GulfFERC Gas Tariff ("Tariff'), as each may be amended from time to time; and WHEREAS, Shipper has requested, and Transporter is willing to provide via construction of the necessary facilities ("Cameron Access Project"), 56,250 Dth/d of such firm transportation service from receipt points on Transporter's interstate pipeline system in order to transport natural gas to a new interconnection point to be developed by Transporter and Cameron LNG, LLC ("Cameron") at Cameron's liquefied natural gas receipt and storage terminal in Cameron Parish, Louisiana, for the purpose of providing natural gas liquefaction and export services consisting of three liquefaction trains that are anticipated to be constructed in phases. NOW THEREFORE, in consideration of the mutual covenants herein contained, the Parties agree as follows: Section 1. Service to be Rendered. Transporter shall perfonn and Shipper shall receive the service in accordance with the provisions of the effective FTS-1 Rate Schedule and applicable General Terms and Conditions of Transp01ier's FERC Gas Tariff, Fourth Revised Volume No. l ("Tariff'), on file with the Federal Energy Regulatory Commission ("Commission"), as the same may be amended or superseded in accordance with the rules and regulations of the Commission herein contained. The maximum obligations of Transporter to deliver gas hereunder to or for Shipper, the designation of the points of delivery at which Transporter shaji deliver or cause gas

3 to be delivered to or for Shipper, and the points of receipt at which the Shipper shall deliver or cause gas to be delivered, are specified in Appendix A, as the same may be amended from time to time by agreement between Shipper and Transporter, or in accordance with the rules and regulations of the Commission. Section 2. Term. Service under this Agreement shall commence on the "Effective Date," which shall be the later of (i) March 14, 2018, or (ii) the date on which Columbia is ready and able to place the Cameron Access Project into service and FERC has been notified that the Cameron Access Project is complete and ready to be placed into service. The initial tem1 of this Agreement shall begin on the Effective Date and shall remain in full force and effect for a term of twenty (20) years (the "Initial Term"). Shipper and Transporter agree to avail themselves of the Commission's pre-granted abandonment authority upon termination of this Agreement, subject to any right of first refusal Shipper may have under the Commission's Regulations and Transporter's Tariff. Notwithstanding the above, Shipper shall have the right, at its option, exercisable by providing notice no later than September 1, 2017 to delay the Effective Date by up to six (6) months (but in no event to a date later than September 1, 2018). Immediately prior to the actual Effective Date (as revised to reflect Shipper's exercise of its rights under Sections 2 or 6 herein), the Parties shall amend this Section 2 to reflect such actual Effective Date and shall further amend this Agreement to reflect the removal of (a) Section 6 (Force Majeure Outage) and (b) Section 7 (In-Service Delay), if inapplicable. Section 3. Contract Extension Right. At the end of the Initial Term, Shipper shall have the light, exercisable no later than six (6) months prior to the end of the Initial Term, to extend the term of this Agreement for an additional term of five (5) years ("Initial Extension"). If Shipper exercises its right to the Initial Extension, Shipper shall have the addhional right, exercisable no later than six (6) months prior to the end of the Initial Extension, to extend this Agreement at the end of the Initial Extension for an additional tenn of five (5) years ("Subsequent Extension"). At the beginning of each such extension, if exercised, Transporter may choose to classify Shipper's rate as a discount and, if Transporter makes such election, Shipper shall execute a discounted rate letter agreement to that effect; provided, however, that, regardless of whether Transporter classifies Shipper's rate as a discount rate, Shipper's actual reservation and commodity rates and volumes during the Initial Extension and the Subsequent Extension shall be as described in the "Extension Rates" portion of the attached Negotiated Rate Letter Agreement; provided further, all other tern1s and conditions of Shipper's service shall remain unchanged. Upon the end of the Subsequent Extension, if exercised, Shipper shall have a Contractual Right of First Refusal with respect to its capacity on the Cameron Access Project in accordance with the Tariff.

4 Section 4. Rates. Shipper shall pay the rates as set forth in the Negotiated Rate Letter Agreement attached hereto as Appendix B (the "Negotiated Rate Letter Agreement") as such rate may be revised in accordance with the conditions set forth in the Negotiated Rate Letter Agreement and Section 5 herein. Shipper shall pay the applicable Tariff FTS-1 Maximum Recourse Rate if at any time an element of the rates as set forth in the Negotiated Rate Letter Agreement is no longer applicable or allowed by the Commission. Section 5. Rate Protection. Notwithstanding the rates reflected in the Negotiated Rate Letter Agreement or anything else to the contrary, if Transporter enters or has entered into a binding contract prior to or within five (5) years of the Effective Date for firm transportation service for (a) a primary term of greater than ten (10) years with another customer (other than (i) a replacement shipper under a capacity release of this Agreement, (ii) the Service Agreement between Transporter and MITSUI & CO. CAMERON LNG SALES, INC., or (iii) the Service Agreement between Transporter and ENGIE S.A., or any assignment thereof or replacement shipper under a capacity release thereof) on all or any portion of the new lateral that is included as part of the Cameron Access Project and (b) whose applicable daily reservation rate or 100 percent load factor equivalent is lower than Shipper's reservation rate or 100 percent load factor equivalent as set forth in the Negotiated Rate Letter Agreement (and which lower rate is not the Cameron Access Project recourse rate or the Transporter pipeline general system recourse rate), then Transporter shall apply the same lower reservation rate to an equivalent amount of Shipper's capacity for the duration of such other customer's contract. Any such rate adjustment pursuant to this Section 5 shall be prospective from the time that the new contract is entered into by Transporter. Section 6. Force Majeure Outage. If one or more events constituting Force Majeure, as defined below occurs with respect to the Cameron LNG Tenninal located in Cameron Parish, Louisiana, Shipper s1rnll give Transporter prompt w1itten notice ("Te1minal Notice") describing the particulars of each occurrence of the Force Majeure. Shipper may elect to delay the Effective Date of this Agreement upon written notice provided by Shipper to Transporter no later than thi11y (30) days after the applicable Te1111inal Notice, by a number of days equal to the duration of such Force Majeure; provided that the maximum delay pursuant to this Section 6 for all Tennina] Notices in the aggregate shall be the lesser of (a) six (6) months or (b) the number of days that would result in an Effective Date of December 1, With respect solely to the Party claiming Force Majeure under this Section 6 (and without changing the force majeure provisions in the Tariff that are applicable upon commencement of service), "Force Majeure" means: any nahtral phenomena or event that such Pmty could not reasonably control, foresee, or prevent, and the occmtence of which such Party has not caused or contributed to (by its negligence or otherwise), which event prevents such Party from perfonning its obligations

5 under this Agreement, including but not limited to: (i) flood, drought, earthquake, unusually severe weather, fire, lightning, tornadoes, washouts, or other Acts of God; (ii) epidemic; war, riot, civil disturbance or disobedience, terrorist acts; sabotage; blockades, arrests, strikes, lockouts or other labor disputes; and (iii) any exercise of sovereign or executive prerogative or similar action by a governmental authority. Notwithstanding the foregoing, the term Force Majeure does not include (i) acts or omissions of any third party, including any materials supplier, vendor, material man, or contractor, unless such acts or omissions are themselves the result of an event that would otherwise satisfy the definition of a Force Majeure event as defined above; (ii) unfavorable market conditions or any changes in market conditions; or (iii) any failure to obtain a permit or authorization from any governmental auth01ity (unless such failure is a delay due to a partial or full government shutdown resulting in a material reduction in funding or staffing of a relevant governmental authority). The failure to prevent or settle any stiike(s), lockout(s) or other labor dispute(s) shall not be considered to be a matter within the reasonable control of the affected Party. Section 7. Severability. In the event that any of the provisions of this Agreement or the Negotiated Rate Letter Agreement are held to be unenforceable or invalid by the FERC or any court of competent jurisdiction, the Parties shall negotiate an equitable adjustment to the provisions of this Agreement or the Negotiated Rate Letter Agreement with a view toward effecting to the extent possible the original purpose of this Agreement and the Negotiated Rate Letter Agreement, and t1rn validity and enforceability of the remaining provisions, or portions or applications thereof, shall not be affected thereby. Section 8. Notices. Notices to Transporter under this Agreement shall be addressed to it at 5151 San Felipe, Suite 2500, Houston, Texas 77056, Attention: Customer Services and notices to Shipper shall be addressed to it at MARUBENI NATURAL GAS AND LNG AMERICA CORP., c/o Marubeni Corporation, LNG Business Sec. II, LNG Dept Ohtemachi, Chiyoda-Ku, Tokyo , Japan, Attention: Iwao Suzuki, General Manager, until changed by either Party by written notice. Section 9. Superseded Agreements. This Agreement supersedes and cancels, as of the effective date hereof, the following Service Agreernent(s): NI A. [The signatures of the Parties immediately follow.}

6 IN WITNESS WHEREOF~ the duly authorized representatives of the Paities hereto have executed this Service Agl.'eement as of the date first written above. MARUBENI NATURAL GAS AND COLUMBIA GULF TRANSMISSION, LLC LNG AMERICA CORP. By : _~-...-=~-.4-/- Name: Name: Title: I }(QT f"f1.fjff1 ot!'f.c \ )ly: f"m{ju, J_ ~ Nrune: Title:

7 Revision No. 0 Appendix A to Service Agreement No Under Rate Schedule FTS-1 between Columbia Gulf Transmission, LLC ("Transporter") and Marnbeni Natural Gas and LNG America Corp.("Shipper") Transportation Demand Begin End Transportation Recurrence Demand Dth/dav Interval I/ 1/ 56,250 1/ 1-12/3 1 Primary Receipt Points Begin End Measuring Measuring Maximum Daily Quantity Recurrence Date Date Point No. Point Name CD th/day) Interval l I 1/ l/1-1 2/31

8 Primary Delivery Points Begin End Measuring Point No. Measuring Point Name Maximum Daily Quantity (Dth/day) Recurrence I/ 11 2/ 2/ l/1-12/31 1 / Pursuant to Options outlined in Attachment A of the Negotiated Rate Letter Agreement 2/ Pursuant to Options outlined in Attachment A of the Negotiated Rate Letter Agreement The Master List of Interconnects ("MLI") as defined in Section 1 of the General Terms and Conditions of Transporter's Tariff is incorporated herein by reference for purposes oflisting valid seconda1y intermptible receipt points and delivery points. Transporter and Shipper have mutually agreed to the following maximum or minimum pressure commitments: Yes _x_no (Check applicable blank) Transpo1ter and Shipper have mutually agreed to a Regulatory Restructuring Reduction Option pursuant to Section 33 of the General Te1ms and Conditions of Transporter's FERC Gas Tariff. _ X _ Yes No (Check applicable blank) Shipper has a contractual right of first refusal upon the end of Shipper's Subsequent Extension, if exercised, equivalent to the right of first refusal set forth from time to time in Section 4 of the General Tenns and Conditions of Transporter's FERC Gas Tatiff. Yes _ x_no (Check applicable blank) This Service Agreement covers interim capacity sold pursuant to the provisions of General Te1ms and Conditions Section 4. Right of first refusal 1ights, if any, applicable to this interim capacity are limited as provided for in General Terms and Conditions Section 4.

9 MARUBENI NATURAL GAS AND LNG AMERICA CORP. COLUMBIA GULF TRANSMISSION, LLC Name: 1<\JS)E'-L. A At+t«tJ Title: ~\ {;?t\,~i~ ~\ By M,,/J)i. ~. ~~A Name: /u..\\,t,ff ).,lto(a}j rn1e: j\w : ' It~ j )?1\17

10 Revision No. 0 Appendix B to Service Agreement No Under Rate Schedule FTS-1 between Columbia Gulf Transmission, LLC (''Transporter") and Marubeni Natural Gas and LNG Ame1ica Corp. ("Shipper") Negotiated Rate Letter Agreement (attached)

11 July 1, 2016 MARUBENI NATURAL GAS AND LNG AMERICA CORP. c/o Marubeni Corporation Attn: Iwao Suzuki, General Manager LNG Business Sec. II, LNG Dept Ohtemachi, Chiyoda-Ku Tokyo , Japan Fax: RE: FTS-1 Service Agreement No Negotiated Rate Letter Agreement Dear General Manager: This Negotiated Rate Letter Agreement between Columbia Gulf Transmission, LLC ("Transporter" or "Columbia") and Maurbeni Natural Gas and LNG America Corp. ("Shipper") shall set forth the applicable rates, calculations thereof, and other rate provisions associated with the transportation service provided by Columbia to Shipper pursuant to the above-referenced Service Agreement (the "Service Agreement"). Columbia and Shipper may be referred to individually as a "Party" or collectively as the "Parties". Shipper and Transporter hereby agree: 1. The "Negotiated Rates" during the primary term for the transportation service provided shall be those rates agreed upon as set forth in Attachment A hereto, as adjusted pursuant to Paragraph 3 ii applicable and Section 4 of the Service Agreement, if applicable. The Negotiated Rates during any extensions shall be those as set forth in Paragraph 7. In addition to the Negotiated Rates, Shipper shall provide the Retainage applicable to Rate Schedule FTS-1, as such may change from time to time. In addition to the other rates and charges, Shipper shall pay any and all demand and commodity surcharges specified in Transporter's FERC Gas Tariff that are applicable to service under Rate Schedule FTS-1 as such may change from time to time.

12 2. For the full term of the Service Agreement (including any extensions) and full volume, Shipper will have the right to access all receipts on the Columbia Gulf system and the Negotiated Rates (with no incremental charge) shall apply when gas is received at any point of receipt on the Columbia Gulf system, including the new interconnect at the Cameron LNG facility, for delivery to the Cameron LNG facility, Florida Gas Transmission (meter 4118), Transcontinental Gas Pipeline (meter 478), Egan Storage (meter 4123), Pine Prairie (meter 4205), Perryville Storage (meter 4235), Jefferson Island (meter 4119), Henry Hub (meter 519), and Texas Eastern Transmission St Landry(meter 479). For deliveries to other interstate pipelines, in addition to the Negotiated Rates, Shipper will pay an incremental daily demand charge of $.05 per Dth, and for gas delivered to any other delivery point, Shipper will pay an incremental daily demand charge equivalent to the then-existing maximum reservation rate for Rate Schedule FTS-1 set forth in Transporter's FERC Gas Tariff. Shipper's primary receipt and delivery points are those found in Appendix A to the above-referenced FTS-1 Service Agreement. 3. Shipper's Base Rates, as applicable and as set forth in Attachment A, shall be adjusted as follows: To the extent Actual Project Costs, as defined below, exceed Estimated Project Costs as defined below, the demand component of Shipper's Base Rates shall be multiplied by the Capital Cost Overrun Factor ("CCO Factor"). The CCO Factor shall be equal to 1 + [(CCO/EPC) X 75%]. In no event shall the CCO Factor exceed To the extent Actual Project Costs, as defined below, are less than Estimated Project Costs as defined below, the demand component of Shipper's Base Rates shall be multiplied by the Capital Cost Underrun Factor ("CCU Factor"). The CCU Factor shall be equal to 1 - [ (CCU/EPC) X 25%]. In no event shall the CCU Factor be less than.95. Any such adjustment shall be made as soon as practical but no later than thirteen (13) months following the date that the Cameron Access Project (as defined in the Service Agreement) is placed in service. "Actual Project Costs" or APC shall mean, subject to any limits on costs as set forth below, all costs and expenses incurred by Columbia, including 2

13 trailing costs up to twelve months subsequent to the Effective Date, to complete the project in the manner contemplated by the Precedent Agreement between Transporter and Shipper (the "Precedent Agreement"), including but not limited to (a) all costs and expenses incurred for the engineering, design, permitting, construction, pipeline and equipment procurement, installation and start-up of the Cameron Access Project facilities, including all compression costs, (b) all costs and expenses incurred for environmental, right-of-way, legal, consultant, construction management, and regulatory activities, (c) all direct and allocated internal overhead and administrative costs, and (d) an allowance for funds used during construction (" AFUDC") computed in accordance with regulations of the FERC. Columbia shall maintain books and records reasonably necessary for Shipper to verify the APC. The Parties acknowledge that Columbia's formal books and records that conform with the FERC and accounting policies and guidelines will not match the APC used to determine Shipper's adjusted base negotiated rate due to the cost cap on internal overheads and administrative costs described in (c) above. In no event shall Actual Project Costs include any amotmt paid or credited by Columbia to Shipper in accordance with Paragraph 4 below or any similar amounts paid (or credited by Columbia) to any other shipper. "Capital Cost Overrun 11 or "CCO" shall be an amount in U.S. dollars equal to the difference between the Actual Project Costs and the Estimated Project Costs, if Actual Project Costs exceed Estimated Project Costs. "Capital Cost Underrun'' or "CCU" shall be an amount in U.S. dollars equal to the difference between the Actual Project Costs and the Estimated Project Costs, if Actual Project Costs are less than Estimated Project Costs. "Estimated Project Costs" or "EPC" shall mean all costs and expenses that are projected to be incurred by Columbia to complete the Cameron Access Project in the manner contemplated by the Precedent Agreement, including but not limited to (a) all costs and expenses projected to be incurred for the engineering, design, permitting, construction, pipeline and equipment procurement, installation and start-up of the Cameron Access Project facilities, including all compression costs, (b) all costs and expenses projected to be incurred for environmental, right-of-way, legal, consultant, construction management, and regulatory activities, (c) all direct and allocated internal overhead and administrative costs, (d) AFUDC computed in accordance with the regulations of the FERC, and (e) a 3

14 contingency amount equal to at least 8% of the total EPC. For purposes of determining the adjustment to Shipper's base negotiated demand rates pursuant to this provision, the Parties agree that the Estimated Project Costs shall be equal to the cost presented to Columbia's Board for authorization of the Cameron Access Project, which is $310,000, Shipper shall have a one-time right, exercised on or before August 31, 2019, to review Columbia's books and records as reasonably necessary to verify Cameron Access Project costs for purposes of this provision. 4. In the event that Columbia has failed to place the Cameron Access Project into service by September 1, 2018 ("In-Service Delay"), Columbia shall pay Shipper the amount described below on account of each day thereafter until the date the Cameron Access Project is placed into service and Columbia is ready and able to provide Service thereon. The amount of such payment ("Payment Amount") shall be an amount per day equal to $0.08 per Dth multiplied by the applicable portion of (but only to the extent Columbia was otherwise obligated hereunder to provide service for such quantities) 37,500 Dth. The Payment Amount will be satisfied by Columbia crediting 1/60th of the aggregate Payment Amount against amounts owed by Shipper under the Precedent Agreement and the Service Agreement in each of the first 60 months following the commencement of Service; provided that if the Precedent Agreement is terminated pursuant to Section 7(c)(iii) of the Precedent Agreement (or is otherwise terminated prior to the 60th month following the commencement of Service), then Columbia shall pay Shipper, within sixty (60) days of such termination, the full remaining Payment Amount in cash. If there is an In-Service Delay, Columbia shall provide Shipper with at least forty-five ( 45) days' notice of the date that the Cameron Access Project will be completed and placed into service and the Service shall commence (A) on the date the Cameron Access Project is placed into service or (B) the first day of the following calendar month. Shipper shall notify Columbia of its choice between (A) or (B) within fifteen (15) days of Shipper's receipt of Columbia's notice. In either event, the Payment Amount shall continue to accrue until such date as Service commences.

15 Columbia and Shipper hereby agree that the actual damages that Shipper would suffer for an In-Service Delay would be substantial and unreasonably difficult to ascertain, and the payment to which Shipper would be entitled hereunder is a reasonable forecast of just compensation for the harm that would be caused by such In-Service Delay, and not a penalty. The payment described herein shall be Shipper's sole and exclusive remedy for any such In-Service Delay (other than Shipper's rights under Section 7(c)(iii) of the Precedent Agreement, if applicable). 5. From and after the Commercial Operations Date (as defined in the Precedent Agreement) for Train 3 (as defined in the Precedent Agreement), Shipper will make an additional payment ("Throughput Commitment Charge") to Columbia if, in any calendar year during the Initial Term and any subsequent term (pro rated for any partial calendar year), Shipper fails to flow at least seventy six percent (76%) of the total demand quantity ("Throughput Commitment"). All scheduled volumes, both primary and secondary, will be credited as actual throughput for purposes of determining whether Shipper has met this requirement. The Throughput Commitment Charge shall be calculated in accordance with the following formula: Throughput Commitment Charge= [(Quantity x Days x.76) - Actual Throughput] x $.05 Where: "Quantity" means the daily transportation demand quantity applicable to Shipper during such calendar year "Days" means the number of days that Service is available during such calendar year "Actual Throughput" means the aggregate volumes of throughput actually made by Shipper during such calendar year Shipper shall pay the Throughput Commihnent Charge for each calendar year, which shall be invoiced on Shipper's bill, for Decembel' service issued the following January. 5

16 Any assignment made by Shipper of part of its entitlement to Cameron Access Project capacity prior to the effective date of the Service Agreement shall reduce Shipper's Throughput Commitment to the extent that Shipper's Quantity is reduced due to such assignment. All volumes scheduled using any portion of Shipper's Quantity through capacity release, if applicable, will be credited to Actual Throughput for use in calculating the Throughput Commitment Charge. 6. In addition to all applicable demand charges hereunder, if any portion of Shipper's Quantity is subject to a capacity release, Shipper shall be responsible each month for any deficiency in Columbia's revenues due to the replacement shipper's payment of a commodity charge lower than the applicable commodity charge described in Paragraph 1 above ("Capacity Release True-Up Charge") during the Initial Term or any subsequent term. The Capacity Release True-up Charge shall be calculated in accordance with the following formula: Capacity Release True-Up Charge= CR Quantity x [Contract Price- CR Price] Where: "CR Quantity" means the aggregate volumes of throughput actually scheduled by the replacement shipper assuming capacity under such capacity release during such month "CR Price" means the per/dth commodity charge exclusive of surcharges paid by the replacement shipper assuming capacity under such capacity release during such month "Contract Price" means the per/dth commodity charge exclusive of stucharges that would have been payable by Shipper for the gas transported absent the capacity release Each month, Shipper shall pay the Capacity Release True-up Charge, which shall be invoiced on Shipper's bill. Columbia agrees that in the event of a capacity release under the Service 6

17 Agreement, Columbia will comment in support of Shipper's efforts to obtain a waiver from FERC permitting it to pass through the Negotiated Rates applicable under this Negotiated Rate Letter Agreement to the shipper assuming capacity under such capacity release. 7. The follmving rates shall be the Negotiated Rates during any extension pursuant to Section 3 of the Service Agreement: Volume 1st 31,250 Dth/d Next 25,000 Dth/d Daily Demand $0.15 $0.14 Daily Commodity $0.035 $ Capitalized terms not otherwise defined in this Negotiated Rate Letter Agreement shall have the meanings set forth in the Service Agreement, or if not defined jn the Service Agreement, in Columbia's FERC Gas Tariff. Accepted and agreed to this 1s 1 day 0 July, Marubeni Natural Gas and NG America Corp. Name:_~tfe_4 V\_V\_~_i' ~~- V\~ltA~\ci~'- Title: y i re 0-to (/fr~~ 1 de;111-r l Columbia Gulf Transmission, LLC Name: '/2 cj,(fcu. It t1!kft.4.j Title: IJlt&T fflg!ioac ByJfu~&.~ Name: AA\u S. kaa-n i<title:"_~_lc_f_~_l'\._e-s_ _i)_e~--- 7

18 ATTACHMENT A Primary Primary Transportation Demand Receipt Point(s)* Delivery Point(s) (Dth/day) Term CenterPoint Energy Cameron 18,750 Dth/day Commencement Gas Transmission Date through (Meter No. 4203) Initial Term Gulf Crossing (Meter Cameron 18,750 Dth/day Scheduled No. 4221) Commercial Operations Date for Train 2 through the Initial Term ETC Tiger (Meter No. Cameron 18,750 Dth/day Scheduled 4232) Commercial Operations Date for Train 3 through the Initial Term Rate Schedule FTS-1 FTS-1 FTS-1 * By notice to Columbia by September 30, 2016, Shipper may reallocate 18,750 Dth/day to Mainline Pool at no additional cost. Commencement Date to Scheduled Commercial Operations Date for Train 2 Volume Daily Demand Daily Commodity 18,750 Dth/d $0.22 $0.00 Scheduled Commercial Operations Date for Train 2 to Scheduled Commercial Operations Date for Train 3 Volume Daily Demand Daily Commodity 37,500 Dth/d $0.22 $0.00 8

19 Scheduled Commercial Operations Date for Train 3 through Initial Term "Base Rates" Volume 1st 31,250 Dth/d Next 25,000 Dth/d Daily Demand $0.15 $0.14 Daily Commodity $0.035 $0.06