TSP Name: Northern Natural Gas Company TSP: 784158214 Notice ID: 105623 Notice Type: TSP Capacity Offering Subject: FIELD AND FIELD TO DEMARC CAPACITY AND ALTERNATE EVALUATION METHODOLOGY Critical: N Post Date/Time: 04/30/2026 04:47 PM Notice Status: Supersede Prior Notice: 103526 For Gas Day(s): 04/30/2026 - 10/31/2026 Notice Effective Date/Time: 04/30/2026 04:45 PM Notice End Date/Time: 11/01/2026 08:59 AM Required Response Indicator Description: 5-No response required Notice Text: Northern is offering customers the option to request formula-based rates in addition to fixed-rate requests for Field Area service for deliveries to Demarc. Capacity will be awarded using the Alternate Evaluation Methodology described below. Northern will not begin evaluating requests for service beginning June 1, 2026, prior to 10 a.m. Wednesday, May 6, 2026. Field and Field to Demarc capacity through October 31, 2026, is limited due to maintenance outages on Northern's system that are posted under Planned Service Outage. Northern has up to 100,000 Dth/day of Field to Demarc capacity available for the period of June 1, 2026, through October 31, 2026. Northern has also evaluated an alternative configuration that would provide up to 6,300 Dth/day of Brownfield South (Group 998R) capacity for the period of June 1, 2026, through October 31, 2026, by reducing the capacity available from Beaver System South (Group 13R) and Pampa South (Group 19R) groups (see the table below). Notable Field Area Capacity beginning June 1, 2026: Current Configuration Alternative Configuration June through October Groups: 998R BROWNFIELD SOUTH 0 6,300 19R PAMPA SOUTH 16,000 6,312 13R BEAVER SYSTEM SOUTH 16,000 6,312 598R SEMINOLE-SUBSYSTEM 0 0 825R MITCHELL TO GAINES 37,000 37,000 Points: 1504R ONEOK WESTEX SEAGRAVES 27,363 27,363 1504D ONEOK WESTEX SEAGRAVES 10,000 10,000 79387R BROWNFIELD POOLING POINT 463,000 463,000 57088R EL PASO/NNG PLAINS 30”(REC) 83,000 83,000 As operational needs change from day-to-day, Northern may have additional Demarc capacity available. Please contact your Marketing Representative if you have questions. Any customer awarded capacity that may be impacted by planned service outages must agree to contractual reduction obligations regardless of rate. Upon notice from Northern, at least 40 hours prior to the start of the Gas Day, customer must reduce the point quantities affected by a maintenance outage unless customer and Northern mutually agree to realign all or a portion of the contract quantity affected by the outage at the contract rate or other mutually agreeable rate. When necessary, Northern will, on a not unduly discriminatory basis, determine the contracts and quantities that must be reduced based upon value to Northern. Northern and customer may agree to extension rights for all or a portion of the contract MDQ awarded. Requests for Service Northern will not sell capacity or grant realignment requests for unsubscribed capacity except as set forth below: ·Requests received 60 calendar days to 0 days prior to the effective date of a contract for five (5) consecutive months or more (consecutive days); ·Requests received 30 calendar days to 0 days prior to the effective date of a contract for the next full month or more (consecutive days); or ·Requests received 7 business days to 0 days prior to the effective date of a contract for a gas day plus any consecutive term. Northern will sell capacity for multiple year terms up to 60 calendar days prior to the effective date for service requested for a minimum of 5 months each year, and if the request for service includes a heating season month (November through March), then all the heating season months must be included. SeeNon-Criticalnotices for additional details of AWARDING OF REQUESTS FOR NEAR-TERM SERVICE. Alternate Evaluation Methodology Northern has the right to aggregate requests, or portions of requests, that generate the highest total NPV to Northern. Northern reserves the right to reject requests at less than max rates. The capacity will be awarded based on a request or combination of requests that results in the highest net present value ("NPV") of revenue on a per unit of capacity basis, using revenues and the Evaluation Periods described below: ·Requests for service beginning between April 2, 2026, and May 1, 2026, will provide NPV through May 31, 2026 ·Requests for service beginning between May 2, 2026, and June 1, 2026, will provide NPV through June 30, 2026 ·Requests for service beginning between June 2, 2026, and July 1, 2026, will provide NPV through July 31, 2026 ·Requests for service beginning between July 2, 2026, and August 1, 2026, will provide NPV through August 31, 2026 ·Requests for service beginning between August 2, 2026, and September 1, 2026, will provide NPV through September 30, 2026 ·Requests for service beginning between September 2, 2026, and October 1, 2026, will provide NPV through October 31, 2026 Northern reserves the right to reject any discounted or negotiated rate request that extends past the Evaluation Period. If such request extends past the Evaluation Period, customer should indicate if they are willing to take the request through only the Evaluation Period. For request evaluation purposes, the assumed reservation component for fixed one-part rate requests will be as the one-part rate less: ·$0.01/Dth/day for receipt points south of the Brownfield compressor station for delivery to points south of the Brownfield compressor station ·$0.035/Dth/day for receipt points north of the Brownfield compressor station for delivery to points south of the Brownfield compressor station ·$0.052/Dth/day for receipt points south of the Brownfield compressor station for delivery to points north of the Brownfield compressor station ·$0.024/Dth/day for receipt points north of the Plainview compression station for delivery to points north of the Plainview compressor station These deductions will be applied to one path of a contiguous one-part request. Index-Based Formula Rates Index-based formula rates will be accepted using the formulas illustrated in the attached Index Rates Formula. Northern will evaluate index-based formula rate requests that use Platts Gas Daily Indices by using the Platts Gas Daily index price assumptions in the tables below. Evaluation Period Index Prices for EvaluationNorthern, demarc ICE ONEOK, Westex Pool El Paso, Permian Waha Panhandle, Tx.-Okla. NGPL, Midcontinent (D) (D) (R) (R) (R) (R) $2.15 ($3.15) ($3.55) ($4.75) $2.05 $2.10 Northern will update this notice when the prices in the table are changed. Index-based formula rate capacity will not be awarded for one hour after the table is updated to allow modifications to requests. The applicable fuel percentages as follows: · 2.36% for primary receipts in MIDs 1-7 to Demarc (Sections 1 and 2 Fuel) · 1.54% for primary receipts in MIDs 8-16A to Demarc (Section 2 Fuel) · 0.90% for Primary receipts in MIDs 1-7 to MIDs 1-7 · 2.44% for Primary receipts in MIDs 8-16A to MIDs 1-7 Contiguous Paths A customer may request contiguous service to increase the value of its bid.A contiguous path is two or more contract paths where the receipt point of one pathisthe same location as the delivery point of another path.For evaluation purposes, the net present value (NPV) calculation of a request with contiguous paths will be determined for each individual path and then added together.For detailed information and examples, seeContiguous Path Details. As previously communicated, Northern filed a Section 4 rate case on July 1, 2025. In an Order dated February 25, 2026, the Chief Judge granted a motion to implement interim settlement rates effective February 01, 2026. For evaluation purposes, Northern's interim settlement rates shall be used as the maximum applicable tariff rates. All winning non-maximum rate requests will be subject to the terms set forth in the "Non-Maximum Rate Terms" see details in Non-Maximum Rate Terms. Customers may request a Rate Adjustment Election structure for the winter months (November through March) which limits the rate exposure on elected quantities (that will not be less than scheduled quantities) where natural gas supply fails to be available by providing a fixed rate in the formula known as component "M." For additional information on the Rate Adjustment election seeRate Adjustment Election Structure. If you have any questions, please contact your account manager.