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Commentary Outlook & Notes Market-Relevant Events Infrastructure Supply Chart Pack
Waha gas prices have been extremely volatile in 2025. The Permian Basin has been operating at the limits of egress even with the addition of the Matterhorn pipeline late last year. Shoulder (Spring/Fall) months haven’t been kind to gas prices in West Texas, as Waha fixed price traded at all-time lows on October 3 at more than -$10.00/MMBtu in the cash market—surpassing levels observed during the worst of Covid. During periods of pipeline maintenance, whether planned or unplanned, spot Waha prices have the potential to turn negative.
Commentary
October 27: Waha gas prices recovered off recent lows as major pipeline maintenance on PHP wrapped up. Gas in West Texas remains under stress as modeled dry gas production is close to 23 Bcf/d with no major pipelines in service until 2H 2026. Looking ahead to November, more pipeline maintenance is expected on PHP between Nov 7–18 of between 325 and 600 MMcf/d. Both the November (nearly expired) and December Waha contracts remain weak at -$3.15 and -$2.13/MMBtu, respectively.
October 3: Maintenance is heavily weighing on Waha cash prices. Waha gas for the weekend package (Oct 4–Oct 6) traded at -$7.00/MMBtu in the morning of October 3. Kinder’s maintenance on PHP has drastically reduced capacity and is the biggest driver of the decline in Waha. While not as extreme as the cash market, prompt Waha fixed price (Nov) settled at -$1.82/MMBtu on October 2, with Waha basis at -$4.66/MMBtu for the same day.
September 12: Prompt Waha basis moved substantially lower on September 12, down to -$3.49 from -$2.75 the day before (prices observed intraday on ICE 9/12/25). With basis trading near -$3.50/MMtu, Fixed priced Waha was at -$0.54/MMBtu at the same time on Friday 9/12. The reason? Likey due to a maintenance notice from Kinder Morgan. The notice said that starting Friday, October 3rd throught October 16th, Permian Highway Pipeline LLC "PHP" operations performing turbine exchanges at two locations. The total Mainline capacity on PHP will be reduced from 2.66 Bcf/d to 1.46 Bcf/d. The Permian basin often operates at the edge of takeaway capacity, so when that capacity is suddendly reduced, expected or unexpected, prices often suffer greatly.
August 12: Waha basis has deteriorated over the past month through the Summer ’26 strip. The prompt-month Waha basis—now on the September contract—has fallen to -$2.21/MMBtu, down from last month’s highs of -$1.45 behind Henry Hub. (Some apples-to-oranges applies here, as last month’s prompt was the August contract.) The Summer 2026 strip has also weakened, dropping to -$2.25 as of August 11. Further out, however, the Winter ’26/’27 strip has strengthened, with basis improving to -$0.73/MMBtu, a much narrower discount than in nearer-term periods. This makes sense given the 4.5 Bcf/d of new Permian takeaway capacity expected to enter service between the second half of 2026 and early 2027. With that expansion, the basin should face less egress pressure, particularly if lower oil prices continue to temper analysts’ forecasts for associated gas growth.
July 11: Gas prices have been flat to slightly improved since our last update. Waha basis has strengthened significantly in the prompt month, as the nearby contract has rolled into summer (August). Further out the curve, the next three seasonal strips have also edged higher, though gains have been more modest. Some of the improvement may be attributed to increased westbound takeaway capacity after maintenance on El Paso ended. However, additional ongoing and new maintenance scheduled for July will again limit egress on El Paso.
June 26: Waha basis has remained relatively flat after recovering from the extreme discounts seen in Q1. It's not just the front of the curve that has stabilized—seasonal basis strips through Winter 26/27 have traded sideways from April through June (see chart pack at the end of the page). While basis levels have held steady, flat price Waha has gradually moved higher, in line with gains at Henry Hub. Cash prices have also firmed, rebounding from negative daily prints as recently as late May. The earlier weakness was driven by pipeline maintenance and elevated Permian production.
Waha Basis Outlook and Notes
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Summer '25
Matterhorn has flowed at higher than anticipated rates with Permian supply at higher than expected levels. Matterhorn should be able to flow more gas this summer as the last 500 MMcf/d becomes available.
There could be times of low cash prices like 2024 in low-demand shoulder months and or times of pipeline maintenance . Cash prices went negative for the first time in 2025 on March, 14.
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Winter '25-'26 & Summer '26
If supply growth is steady (oil prices), then 2Q ’25 through late ’26 is a period of price concern. The Permian’s next takeaway project doesn’t come online until 3Q of ’26. Similar to Summer 25 in terms of price risks
Possible overbuild in outbound capacity as Blackcomb, GCX expansion, and Hugh Brinson come into service
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Winter '26-'27 & Summer '27
The overbuild concept continues into 2027 as Hugh Brinson comes online. The Waha forward curve is priced at a lesser discount to Henry hub during this period as there should be excess capacity out of the Permian.
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For more discussion on basis price moves and the current forward curves:
For more discussion and charts, jump to our outlook and chart pack. Remember, the local market is influenced by the broader gas market. Consult our Gas Macro Outlook for more.
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Recent Market-Relevant Events
8.25.2025
WhiteWater and Partners to announce new 2.5 Bcf/d Permian-to-Katy natural gas pipeline
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8.6.2025
Energy Transfer to Build $5.3 Billion Texas-to-Arizona Gas Pipeline
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5.15.2025
Tallgrass Announces Precedent Agreeements for a new Permian Pipeline to Rockies Express
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The basin suffers from persistent oversupply compared to the amount of egress pipeline capacity. This affects the gas market more than it does crude oil, mostly because of aggressive additions in oil takeaway due to oil’s larger revenue share for almost all operators in the area.
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As of 10/03/2025
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For a discussion of production outlook:
Below are the most market-relevant infrastructure projects that appear to be funded and going forward. The projects that offer intra-region capacity (egress) are also shown in the chart above.
Note: Deeper discussion included below the map.
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Gas Pipeline Projects
Matterhorn Pipeline
In-service date: 3Q 2024
Capacity: 2.5 Bcf/d
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Source: WhiteWater
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Matterhorn Pipeline - Whitewater Midstream's 2.5 Bcf/d pipeline entered service in the fall of 2024. The pipe originates in Waha and moves gas toward Katy, Texas.
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Blackcomb
In-service date: 2H 2026
Capacity: 2.5 Bcf/d
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Source: WhiteWater
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Blackcomb - WhiteWater Midstream and Targa are moving ahead with building a new 42-inch, 365-mile natural gas pipeline from the Permian Basin in West Texas to the Agua Dulce hub in South Texas. The startup timeline is 2H 2026 and will transport up to 2.5 Bcf/d.Shippers include Devon, Diamondback Energy, Marathon Petroleum, and Targa. Will source in the Midland Basin and the 3 Bcf/d Agua Blanca pipeline system in the Delaware Basin owned by WhiteWater and MPLX.
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Gulf Coast Express (Expansion)
In-service date: 2Q 2026
Capacity: 0.60 Bcf/d
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Source: Kinder Morgan
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Gulf Coast Express Expansion - Kinder Morgan announced the start of an open season for the Gulf Coast Express expansion on May 16, 2022. The project entails adding compressors to the GCX pipeline to enhance its capacity from the Permian Basin to South Texas markets by 570 MMcf/d. The project is expected to be operational mid-2026, subject to additional customer agreements. Kinder's 3Q 2025 earnings call deck showed a 2Q26 in-service date.
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Hugh Brinson
In-service date: Q4 2026
Capacity: 1.5 Bcf/d
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Source: Energy Transfer
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| Hugh Brinson - The Hugh Brinson Pipeline Project, formally know as Warrior, will be built in two phases. Phase I consists of roughly 400 miles of 42-inch pipeline running from Waha and the Midland Basin to Maypearl, Texas. The majority of the pipe steel has been secured and is being manufactured in U.S. mills. Phase I is designed for about 1.5 Bcf/d, is fully sold out under long-term, fee-based commitments with investment-grade counterparties, and will use Energy Transfer’s network south of the DFW metroplex to reach major trading hubs and markets. In-service is targeted for Q4 2026. Phase I also includes the Midland Lateral—a 42-mile, 36-inch line that will connect Energy Transfer processing plants in Martin and Midland counties to the mainline. Phase II adds compression, creating a bi-directional system able to move roughly 2.2 Bcf/d from west to east and about 1 Bcf/d from east to west. At start-up, more than 2.2 Bcf/d is expected to be under contract. Total capital for Phases 1 and 2 is estimated at approximately $2.7 billion. Source: ET |
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Energy Transfer Transwestern Desert Southwest Pipeline Expansion Project
In-service date: Q4 2029
Capacity: 1.5 Bcf/d
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Source: Energy Transfer
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| Desert Southwest Pipeline Project - The Desert Southwest Pipeline Project is a 516-mile, 42-inch natural gas line that would run from the heart of the Permian Basin to the Phoenix area of Arizona. It is expected to have about 1.5 Bcf/d of capacity and to increase supply to markets across Arizona and New Mexico from Energy Transfer’s Permian asset base. The project is backed by significant long-term commitments from investment-grade customers, is estimated to cost roughly $5.3 billion (including about $0.6 billion of AFUDC), and targets an in-service date in Q4 2029. An open season is planned for Q3 2025, with the remaining capacity expected to be fully subscribed upon completion, and the project could be efficiently expanded depending on the open-season results to accommodate additional demand. Source: ET |
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Eiger Express Pipeline
In-service date: 1H 2028
Capacity: 2.5 Bcf/d
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| Eiger Express Pipeline - The Eiger Express Pipeline is designed to transport up to 2.5 billion cubic feet per day (Bcf/d) of natural gas through approximately 450 miles of 42-inch pipeline from the Permian Basin in West Texas to the Katy area. Supply for the Eiger Express pipeline will be sourced from multiple connections in the Permian Basin, including gas processing facilities in the Midland Basin, and from the Delaware Basin via the Agua Blanca Pipeline, a joint venture between WhiteWater, Enbridge and MPLX. Source: WhiteWater |
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Other Projects
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Kinder Morgan's Copper State Connector (no FID) - The proposed project is a 630-mile, 42-inch greenfield pipeline capable of transporting 2.1 billion cubic feet per day (Bcf/d) from Waha to Arizona. During Kinder Morgan’s Q2 2025 earnings call, company representatives appeared to downplay the initiative when questioned by analysts, citing a competitive environment and uncertainty regarding tariff costs. Click here for the link to Kinder's comments in Docket G-00000A-25-0029 filed in February 2025 with the Arizona Corporation Commission.
Saguaro Pipeline (2028 no FID) - The pipeline is proposed to run from the Waha Gas Hub in the Permian Basin in West Texas, U.S. to the Mexican border in Hudspeth County, Texas. The pipe would be 2.8 Bcf/d at 48" diameter, owned by ONEOK. This pipe's future depends on whether Mexico's Pacific LNG reaches FID (expected 2025). If this is built, the Permian has more of a chance to be overbuilt with takeaway pipe through 2030.
Northbound Pipeline Expansions
Natural Gas Pipeline of America (NGPL) - Added compression to increase northbound capacity by 50 MMcf/d. Planned in-service of October 2025.
Northern Natural Gas - Expansion of 87 MMcf/d. In-service by November 2025.
Transwestern - Expansion of 80 MMcf/d. In-service by November 2026.
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Local Supply
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Based on public operator guidance, midstream company outlooks, pricing trends, and recent drilling activity, we anticipate continued growth in both oil and gas production in the Permian Basin, albeit at a slower pace than in the past two years. Historically, Permian gas supply has closely followed available pipeline takeaway capacity, meaning gas is always waiting when infrastructure allows. However, the trajectory of future oil supply growth may be more measured, as operators exhibit greater capital discipline. This moderation in oil production could result in a flatter gas supply growth profile, even with rising gas-to-oil ratios (GOR) and increased drilling in lower-liquids areas.
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Operator Guidance
Diamondback Energy (Q3 2025 EC)
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11/04/2025
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2025 Guidance:
FY25 Gas Production: ~440 MMcf/d (Q3 actual; +1.7% Q/Q, +5.2% Y/Y)
FY25 Total Production: 910–920 MBOE/d (raised from prior 890–910 MBOE/d)
FY25 CapEx: $3.45–$3.55B (tightened range; down $500M vs original guide)
Q4 Maintenance CapEx: ~$925M (used as baseline for 2026 planning)
Natural Gas Hedging:
Outright Price Protection:
Q4 2025: 690,000 MMBtu/d ($2.49 floor / $5.28 ceiling)
2026: 840,000 MMBtu/d ($2.87 / $6.35)
2027: 580,000 MMBtu/d ($2.91 / $6.37)
Basis Swaps:
Waha: 610–300K MMBtu/d (-$0.98 to -$1.35)
HSC: 20–120K MMBtu/d (-$0.49 to -$0.25)
30% of gas volumes expected to receive non-Waha pricing by YE26
Gas Strategy & Infrastructure:
Waha Exposure: 70% → 40% by YE26
Pipeline Access:Current: Whistler, Matterhorn
2026+: Blackcomb (200–250 MMcf/d), Hugh Brinson (eastbound)
Power Strategy:
50 MMcf/d committed to Basin Ranch Power Plant (1.3 GW, operational by 2029)
Evaluating behind-the-meter and data center partnerships
Capital Efficiency & Drilling:
Q3 CapEx: $774M (↓10% Q/Q)
Well Costs:
Midland Basin: $550–$580/ft
Delaware Basin: $860–$910/ft
Analyst Q&A Takeaways:
Macro View: “Yellow light” posture continues; watching supply-side signals
Technology:
Testing extended laterals (up to 20,000 ft)
Focus on lowering reinvestment rate via base production enhancement
Acidization and stimulation trials to optimize PDP recovery
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Devon Energy (Q3 2025 EC)
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11/06/2025
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2025 Guidance:
Lease Acquisitions: ~$170M for ~60 net locations (July–August)
Wolfcamp B: ~30% of 2025 program; performing at or above expectations
Zone Mix (2025): ~30% Wolfcamp B/Deep Wolfcamp, ~30% Bone Spring, ~30% Wolfcamp A, remainder Avalon
D&C Efficiency:
New record: 1,800 ft/day
AI-driven drilling optimization reduced tripping, curve drilling, and casing times by ~30%
Smart Gas Lift: Full deployment underway in Delaware; 3–5% uplift in production
Workover Optimization: Reduced pad time, improved uptime, added ~2 MBbl/d net production
GP&T & NGL Contract Restructuring: $200M in annual savings expected by YE25
Strategic & Infrastructure Highlights:
Cotton Draw Midstream: Full ownership acquired; $50M in annual distribution savings
WaterBridge JV: 14% stake retained; strategic for water handling and pore space access
Gas Marketing:
50 MMcf/d LNG export deal (10 years, starts 2028)
65 MMcf/d in-basin power deal (7 years, starts 2028)
Matterhorn Pipeline: Divested for $372M; takeaway capacity retained
Analysts Q&A Takeaways:
Base Production Optimization: +20 MBOE/d uplift vs. baseline; $150M FCF benefit
LOE: Down ~6% YTD; further reductions expected in 2026
Well Count: 2025 program reduced by ~20 wells due to efficiency gains
M&A: Active in New Mexico lease sales; Delaware remains core focus
Portfolio Review: Ongoing evaluation of non-core assets (e.g., Anadarko, PRB)
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Coterra Energy (Q3 2025 EC)
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11/04/2025
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2025 Guidance:
FY25 Permian Oil Production: ~72% liquids mix of 367 MBOE/d in Q3
FY25 Permian D&C CapEx: $1.56B (in line with February guidance)
FY25 Net Wells Online: ~165 (upper end of guidance range)
Avg. Lateral Length: ~10,200 ft
Avg. Well Cost: $950/ft (↓10% YoY)
Primary Targets: Upper & Lower Wolfcamp, Bone Spring
Drilling & Basin Activity:
Franklin Mountain & Avant Acquisitions:
10% increase in inventory footage via trades, leasing, and delineation
10% reduction in well costs via optimized casing design and stimulation
5% LOE reduction to date; targeting 15% run-rate savings
Microgrid Development:
3 new microgrids in planning; potential to cut power costs by 50%
$25–50M in annual savings expected as power demand grows
Major Projects:
Barbell Row (Phase 1) and Bowler Row performing well; contributing to Q3 oil beat
Operational Efficiency:
Drilling times reduced from 15 to 13 days for 2-mile laterals
Scale and pad design driving down D&C and midstream costs
Strategic & Infrastructure Highlights:
CPV Power Deal: 50 MMcf/d gas supply to Basin Ranch Power Plant (Permian)
Gas Marketing:
Evaluating new long-haul pipeline access to reduce Waha basis exposure
Actively pursuing flow assurance and NYMEX-linked pricing
Analysts Q&A Takeaways:
Permian well productivity tracking at or above expectations
2026 CapEx expected to be modestly down; Permian activity to remain steady
Continued cost compression expected in Northern Delaware via pad scale and trades
Lightweight proppant trials underway in Delaware; results pending
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Energy Transfer (Q3 2025 EC)
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08/06/2025
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2025 Guidance:
Permian Gas Processing Capacity: ~5.4 Bcf/d across multiple plants
Q3 2025 Permian Processing Volumes: Reached new record levels
Permian NGL Transportation Volumes: Up 11% YoY; new partnership record
Permian Midstream Gathered Volumes: Up 3% YoY
Drilling & Basin Activity:
Plants Online:
Lenorah I & II (200 MMcf/d each): Both in service; Lenorah II running at full capacity
Badger (200 MMcf/d): In service; ramping to full capacity
Plants Under Construction:
Mustang Draw I (275 MMcf/d): In service Q2 2026
Mustang Draw II (250 MMcf/d): In service Q4 2026; FID reached
Processing Optimizations:
Added ~50 MMcf/d at four plants for total incremental ~200 MMcf/d
Midland Lateral:
42-mile, 36-inch pipeline connecting ET plants to Hugh Brinson Pipeline
Data Center & Power Demand Growth:
Oracle Agreements:
Supplying ~900,000 Mcf/d to 3 data centers (2 in Texas)
First flows by YE 2025; full completion mid-2026
Fermi America Agreement:
300,000 MMBtu/d to Amarillo HyperGrid campus (subject to election)
Entergy Louisiana Agreement:
250,000 MMBtu/d firm transport starting Dec 2028; 20-year term
Analysts Q&A Takeaways:
Hugh Brinson expected to be Energy Transfer’s most profitable asset due to strategic location and demand-pull contracts
Permian gas supply demand expected to grow 12–15% to meet announced pipeline capacity needs
Data center deals are low-capital, high-return; many involve short laterals or leverage existing infrastructure
Considering conversion of one Permian NGL pipeline to natural gas service due to higher revenue potential
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Occidental Petroleum (Q2 2025 EC)
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08/07/2025
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2025 Guidance:
Total Company Production:
Full-year: ~1.17 MMBOE/d
Q2 2025: 1.175 MMBOE/d
Permian Production Outlook:
Full-year production trending at ~620 MBOE/d, in line with expectations
Q2 Permian output: ~618 MBOE/d
Total Capital Program (2025):
Reaffirmed at $6.4B (unchanged from previous guide)
Drilling & Basin Activity:
Delaware Basin:
Leading activity area; 2025 CapEx prioritized here
80% of Permian wells expected to be in Delaware in 2025
Targeting continued improvements in cycle times and well costs
Midstream & Marketing:
Exported ~70% of Permian crude volumes in Q2
Using owned VLCC capacity and long-term contracts to Gulf Coast refineries and international buyers
Analysts Q&A Takeaways:
Permian Optimization:
Oxy emphasized flat cost trajectory, noting improvements in pad design and water handling
"Our Delaware program is flat YoY despite broader inflation pressures."
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Local Demand
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The Permian Basin is a supply zone with limited local demand relative to other areas in the US. Local gas demand can range from 400 MMcf/d and 700 MMcf/d depending on the season.
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Wind and Solar Projects: The Permian Basin's sunny climate and high wind speeds make it an attractive location for renewable energy development. This increases competition in the power market and influences grid dynamics.
Infrastructure Limitations: Limited transmission capacity can bottleneck power flows from generation sites (e.g., gas plants or renewables) to demand centers.
Congestion Pricing: Transmission constraints often lead to price volatility and localized pricing spikes.
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Market Design: The Permian Basin straddles the boundaries of the Electric Reliability Council of Texas (ERCOT) and the Southwest Power Pool (SPP), each with different market designs and rules that influence pricing and operations.
Environmental Regulations: Policies targeting emissions and flaring can shift market dynamics by incentivizing renewable energy or penalizing gas flaring.
Data Centers and Electrification: The rise of data centers and electrification of oilfield operations (e.g., electric drilling rigs) also adds to power demand.
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Recent Market-Relevant events
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WhiteWater announces new Permian-to-Katy Natural Gas Pipeline
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Market Impact: The pipeline is likley to follow Matterhorn's easement as the pipeline will be operated by WhiteWater and flows to Katy, Texas. Gas reaching the Katy area will soon have the capability to connect to both Blackfin and Trident that will take gas around Houston toward growing LNG demand.
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The Eiger Express Pipeline is designed to transport up to 2.5 billion cubic feet per day (Bcf/d) of natural gas through approximately 450 miles of 42-inch pipeline from the Permian Basin in West Texas to the Katy area.
- Design capacity of the pipeline is 2.5 Bcf/d and estimated in service date by 1H 2028.
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The Eiger Express Pipeline is a joint venture owned 70% by the Matterhorn JV, 15% by ONEOK, and 15% by MPLX. ONEOK's and MPLX's direct ownership interests in the Eiger Express Pipeline joint venture are incremental to their ownership through the Matterhorn JV, resulting in 25.5% and 22% ownership in the pipeline, respectively.
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The Eiger Express Pipeline will be constructed and operated by WhiteWater and is expected to be in service in mid-2028, pending the receipt of customary regulatory and other approvals.
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Energy Transfer to Build $5.3 Billion Texas-to-Arizona Gas Pipeline
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Market Impact: Would provide more naturqal gas takeway capacity for the Permian basin. It would also better supply the desert southwest and possibly help feed the Mexican Costa Azul LNG facility.
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The pipeline expansion of Transwestern would consist of 516 miles of 42-inch pipeline and nine compressor stations in Arizona, New Mexico, and Texas.
- Design capacity of the pipeline is 1.5 Bcf/d and estimated in service date by 4Q 2029.
- The project is supported by long-term agreements from invenstment-grade customers and the compay plans to launch an open season later this quarter.
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Tallgrass Proposes new Permian to Rockies Express Pipeline
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Market Impact: The new proposed pipeline could serve a varity of demand centers depending on where it would connect with Rockies Express (REX). Rockies gas production has been on the decline and is expected to continue into the future. Tallgrass has an extensive pipeline system in the Rockies that can reach the West Coast and demand centers in the Midwest.
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Tallgrass anounced anchor shipper precedent agreementsfor a new pipeline that will move gas from the Permian Basin to the Rockies Express Pipeline and other points of delivery.
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The company said there are sufficient agreements to financially justify construction of the project with an in-service date in late 2028.
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WhiteWater Announces FID on Traverse Pipeline
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Market Impact: This pipe is important for moving gas toward the Houston and eventually, toward LNG in Louisiana. However, it does not add extra egress for those exposed to Waha gas prices.
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WhiteWater, MPLX LP, and Enbridge Inc., have partnered with an affiliate of Targa to move forward with the construction of the Traverse Pipeline.
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The Traverse Pipline will be a bi-directional, 160 mile, 36-inch pipeline along the Gulf Coast between Agua Dulce in South Texas and the Katy area.
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The pipeline will transport up to 1.75 Bcf/d and will be sourced from multiple locations such as Whistler, Blackcomb, and Matterhorn Express Pipeline.
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Expansion of NGL and Natural Gas Takeaway From MPLX with Gulf Coast Projects
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Market Impact: Added gas processing and pipeline expansions in the Permian will mean more gas reaching the Gulf to feed LNG growth through the end of the decade.
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MPLX reported a significant uptick in its natural gas and NGL services in late 2024
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New infrastructure includes the Gulf Coast fractionation complex, which will feature two 150 MBbl/d facilities, anticipated to come online by 2028 and 2029
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The company is also working with ONEOK to build a 400 MBbl/d LPG export terminal and pipeline that is expected to come online in 2028
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MPLX also mentioned that the Blackcomb and Rio Bravo Pipelines will enhance natural gas transport from the Permian to the Gulf Coast. The company is also boosting natural gas processing facilities, including the Secretariat processing plant in the Permian. The new facilities are expected to add 1.4 Bcf/d of processing capacity by late 2025.
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Blackfin Pipeline gets approval to build lateral connection to LNG
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Market Impact: A connection between Blackfin and CP Express means Permian gas could flow down Matterhorn—another WhiteWater pipeline—to Blackfin, then to CP Express and CP2 LNG. This, along with Kinder Morgan’s FID-approved Trident Pipeline, would help debottleneck the Katy and Houston area and route gas around Houston to the Beaumont/Port Arthur area.
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The Blackfin Pipeline, owned by WhiteWater Midstream, was approved by the RRC on Jan. 28 for the addition of two laterals, including a 0.55-mile, 48-inch CP Express Delivery Lateral.
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The CP Express Pipeline will deliver gas from far southeast Texas to Venture Global's proposed CP2 LNG project in Cameron Parish, Louisiana.
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The other approved lateral, called the Matterfin Lateral, is 0.2 miles long and would likely link to the Matterhorn Express Pipeline, allowing West Texas gas to connect more easily to Louisiana LNG.
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Blackfin started construction on the mainline in October 2024, according to RRC data.
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Energy Transfer reaches FID on 2.2 Bcf/d Permian pipeline
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Market impact: The addition of the Hugh Brinson pipeline in the winter of '26/'27 will likely add to the region's pipeline takeaway capacity overbuild. The Waha forward curve in 2027 reflects this reality.
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Previously known as the Warrior Pipeline. The pipe has been renamed to Hugh Brinson.
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The project is a 400 miles of 42" pipeline with an initial capacity of 1.5 Bcf/d.
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Phase II will boost pipeline capacity to 2.2 Bcf/d, depending on demand.
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