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U.S. Coal Production (MMst)

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Consumption by Sector (MMst)

Exports & Imports (MMst)

Coal Generation — TWh (bars) & Share % (line)

Top U.S. Coal Producing States — 2024

#	State	Region	2023 MMst	2024 MMst	YoY	% U.S.	Type
1	Wyoming	Powder River Basin	237.3	190.7	▼19.6%	37.2%	Sub-bituminous
2	West Virginia	Appalachia	84.6	79.5	▼6.0%	15.5%	Bituminous/Met
3	Pennsylvania	N. Appalachia	42.6	42.2	▼0.9%	8.2%	Bituminous/Met
4	Illinois	Illinois Basin	33.2	34.2	▲3.0%	6.7%	Bituminous
5	Kentucky	Appalachia	32.1	29.8	▼7.2%	5.8%	Bituminous
6	Montana	Powder River Basin	40.3	27.0	▼33.0%	5.3%	Sub-bituminous
7	North Dakota	N. Great Plains	24.2	23.5	▼2.9%	4.6%	Lignite
8	Colorado	Rocky Mountain	14.5	13.8	▼4.8%	2.7%	Bituminous
Source: EIA Annual Coal Report 2024 (Nov 2025). 2024 figures are EIA actuals. MT 2023 baseline may also need revision; MT 2024 decline driven by Absaloka closure (Apr 2024) and Spring Creek/Signal Peak declines.

Powder River Basin — America's Coal HeartlandThe PRB in Wyoming and Montana produces ~37% of all U.S. coal from 16 major surface mines. Its low-sulfur sub-bituminous coal (8,400–8,800 Btu/lb) dominates electric power supply in the Midwest and Southeast. PRB 8800 Btu spot prices are the primary fuel-switching indicator vs. Henry Hub natural gas.

Annual reference figures — KPI tiles below show 2024 production data and Q1 2026 reference pricing (snapshot Jan 2026). The chart "PRB 8800 Btu Spot Price" auto-refreshes from EIA; tile values do not.

PRB Production (2024)

217.7 MMst

WY 190.7 + MT 27.0 • ▼ 19.6% YoY · reference

PRB 8800 Spot (Q1 2026)

$14.95/st

Stable YoY • Argus/S&P Global Jan 2026 · reference

Wyoming Output (2024)

190.7 MMst

37.2% of U.S. total production · reference

Active PRB Mines

16

All surface operations • MSHA 2024

Wyoming vs Montana PRB Production (MMst)

PRB 8800 Btu Spot Price ($/short ton)Argus · snapshot

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PRB Mine Production — Market Share (2024)

Source: EIA Annual Coal Report / MSHA 2024. NTEC mines highlighted.

Major PRB Mines — 2024 Production (EIA Table 9 / MSHA)

#	Mine	State	Company	2024 Prod (MMst)	% PRB	Btu/lb
1	North Antelope Rochelle	WY	Peabody Energy	59.8	28.2%	8,800
2	Black Thunder	WY	Core Natural Resources	44.5	21.0%	8,800
3	Antelope	WY	Navajo Transitional Energy	15.0	7.1%	8,850
4	Belle Ayr	WY	Eagle Specialty Materials	14.6	6.9%	8,800
5	Spring Creek	MT	Navajo Transitional Energy	13.1	6.2%	9,350
6	Eagle Butte	WY	Eagle Specialty Materials	11.0	5.2%	8,800
7	Caballo	WY	Peabody Energy	10.8	5.1%	8,400
8	Rawhide	WY	Peabody Energy	9.0	4.3%	8,400
9	Signal Peak	MT	Global Mining Group	7.1	3.3%	12,700
10	Buckskin	WY	Kiewit Mining Group	6.8	3.2%	8,400
NTEC mines highlighted (Antelope, Spring Creek). Cordero Rojo (NTEC) dropped to 4.3 MMst (#12). Eagle Butte & Belle Ayr owned by Eagle Specialty Materials. Sources: MSHA Production Data 2024; EIA Table 9. Top-10 sum: 212.0 MMst · full WY+MT PRB total: 217.7 MMst (top-10 + 5.7 MMst across remaining ranked mines).

Market Intelligence — PRB Coal Market AnalysisConsolidated view of buyer activity, plant retirements, pricing, stockpiles, and fuel switching economics. Data sourced from EIA Forms 923/860, EPA CAMPD, EIA STEO, and market pricing services.

Reference data — the Buyer Landscape, Plant Closures, and 52-week Pricing sub-tabs below contain manually-curated snapshots through early Apr 2026. Stockpiles & Fuel Switching pull from EIA STEO automatically. Treat snapshot views as a reference baseline, not today's market.

Reference data — EIA Form 923 (2024 annual). The 26-plant table, KPIs, and the four charts are sourced from the most recent annual EIA filings (2024) plus a Mar 2026 plant-status overlay. EIA refreshes 923 annually; treat as a stable reference, not real-time.

Total PRB Receipts

38.6M tons

26 tracked plants • EIA Form 923 (2024)

Avg Delivered Cost

$25.28/ton

Range: $21.85–$29.10 · 2024

Avg BTU Content

12,001Btu/lb

Avg sulfur 0.38% • Ash 5.15% · 2024

At-Risk Capacity

4.3GW

Plants w/ retirement ≤2030 · 2024 Form 860

PRB Coal Receipts by Plant (Top 15 — ktons, 2024)

Delivered Cost by Plant ($/ton, 2024)

PRB Buyer Distribution by State

Plant Capacity vs. Retirement TimelineEIA 860 · 2024

PRB Coal Buyer Detail — EIA Form 923 (2024 Annual) View NTEC Contracts →

Plant ↕	State	Utility	Receipts (tons) ↕	$/ton ↕	$/MMBtu	Avg BTU	Sulfur %	Capacity (MW)	Retire Year	Status
Laramie River Station	WY	Rocky Mountain Power	2,847,000	$22.50	$1.89	11,875	0.35%	1,710	2040	Operating
Jim Bridger	WY	PacifiCorp	2,134,000	$21.85	$1.82	12,010	0.42%	2,441	2039	Operating
Plant Scherer	GA	Georgia Power	2,234,000	$26.75	$2.24	11,925	0.39%	3,520	2042	Operating
Jeffrey Energy Ctr	KS	Evergy	2,001,000	$23.75	$1.98	11,980	0.36%	2,215	2039	Operating
Labadie	MO	Ameren	1,789,000	$25.50	$2.13	11,980	0.38%	2,156	2042	Operating
Martin Lake	TX	Luminant	1,823,000	$28.50	$2.38	11,950	0.41%	2,379	2038	Operating
Council Bluffs	IA	MidAmerican Energy	1,678,000	$22.40	$1.87	11,975	0.38%	1,725	2038	Operating
Colstrip	MT	Talen Energy	1,645,000	$24.35	$2.03	12,020	0.39%	2,095	2035	Deferred
Dave Johnston	WY	Rocky Mountain Power	1,567,000	$23.10	$1.91	12,115	0.38%	816	2027	Retire 2027
LaCygne	KS	Evergy	1,567,000	$23.85	$1.99	12,020	0.37%	1,395	2037	Operating
Rush Island	IL	Ameren	1,567,000	$24.50	$2.04	12,020	0.38%	1,535	2037	Operating
Sooner	OK	OGE Energy	1,456,000	$25.20	$2.10	12,000	0.40%	1,890	2037	Operating
Plant Miller	AL	Southern Company	1,456,000	$27.25	$2.28	12,010	0.37%	2,640	2040	Operating
Ottumwa	IA	MidAmerican Energy	1,456,000	$22.55	$1.88	12,005	0.39%	1,640	2040	Operating
Independence	AR	Entergy	1,345,000	$26.85	$2.24	12,015	0.37%	1,695	2039	Operating
White Bluff	AR	Entergy	1,287,000	$26.60	$2.22	12,010	0.38%	1,645	2038	Operating
Welsh	TX	Vistra	1,234,000	$28.75	$2.40	11,980	0.40%	1,674	2037	Operating
Gerald Gentleman	NE	Lincoln Electric	1,234,000	$22.95	$1.92	12,015	0.35%	1,260	2040	Operating
Rush Power	MO	Ameren	1,234,000	$25.30	$2.11	11,990	0.37%	1,080	2035	Operating
Muskogee	OK	AES Corporation	1,189,000	$25.90	$2.16	11,995	0.39%	1,550	2036	Operating
Harrington	TX	Reliant Energy	1,123,000	$28.40	$2.37	11,975	0.39%	1,080	2036	Operating
Conemaugh	PA	GenOn	1,089,000	$26.75	$2.23	12,015	0.40%	1,946	2039	Operating
Parish	TX	NRG Energy	987,000	$28.95	$2.41	12,005	0.41%	1,210	2038	Operating
Monticello	TX	TXU Generation	956,000	$29.10	$2.43	12,000	0.36%	760	2035	Operating
North Omaha	NE	OPPD	956,000	$23.10	$1.93	12,010	0.36%	1,150	2038	Operating
Johnstown	PA	GenOn	945,000	$26.85	$2.24	11,995	0.39%	1,445	2036	Operating
Source: EIA Form 923 Annual (2024) • EIA Form 860 (2024) • Plant status as of Mar 2026. Sorted by receipts descending.

NOAA Outlook — Apr–Jun 2026

Region	Temp	%	Signal
National	Above Nml	55%	Bullish
Midwest	Above Nml	50%	Bullish
South Central	Above Nml	55%	Bullish
Southeast	Above Nml	50%	Bullish
N. Plains	Above Nml	55%	Neutral
Mid-Atlantic	Above Nml	50%	Bullish

ENSO: Neutral → El Niño (62% prob by summer). Above-normal CDD = elevated coal burn. Source: NOAA CPC Mar 2026.

PRB Demand-at-Risk Waterfall

Period	Tons at Risk	Remaining	%
Current	—	38.8M	100%
2027	-1.6M	37.2M	96%
2031–35	-3.8M	33.4M	86%
2036–40	-29.4M	4.0M	10%
2041+	-4.0M	0	0%

20 plants (29.4 Mst) cluster in 2036–40 retirement cliff. Near-term risk limited. Source: EIA Forms 923/860.

U.S. Coal vs Natural Gas Generation — Monthly net generation (MWh) for the U.S. electric power sector, all sectors aggregate. Sourced from EIA Form 930 / electric-power-operational-data, refreshed each EIA connector run. History begins Jan 2019.

Q1 Totals by Year (MWh, thousands)

Year	Q1 Coal	Q1 Gas	Coal YoY	Gas YoY

Monthly Detail (latest 6 years, MWh thousands)

Cumulative U.S. Generation by Year (MWh, thousands)

Monthly U.S. Generation (MWh, thousands)

Manually maintained — DOE §202(c) order details and the deferrals table below were last reviewed on Mar 30, 2026. Verify with DOE/utility filings before quoting in regulatory or legal contexts.

DOE Emergency Orders Update — Gibson & Centralia Orders Expired (March 2026)The Trump Administration invoked Federal Power Act §202(c) emergency authority 16+ times since May 2025. Gibson IN (~1,500 MW, expired Mar 23) and Centralia WA (~660 MW, expired Mar 16) orders are now lapsed. Craig Station CO (~430 MW) order extended Mar 30 through June 2026; J.H. Campbell MI (1,331 MW) remains active through May 18, 2026. In 2024 operators planned 12.3 GW of retirements but only retired 4.6 GW — the lowest since 2008. For 2026, 6.4 GW is currently scheduled including the 1,231 MW Cumberland Unit 2 (TN) with no active deferral.

2024 Planned vs Actual

4.6/12.3 GW

Only 37% of planned retirements occurred

2025 Planned Retirements

8.1 GW

4.7% of fleet • Several deferred by DOE

Current Fleet (YE 2024)

172 GW

Down from 286 GW in 2015 (−40%)

Post-Retire Fleet (2026F)

~159 GW

If all planned retirements proceed

Planned vs Actual Retirements (GW)EIA · reference

U.S. Coal Fleet Capacity (GW)EIA · reference

Notable Plant Deferrals & DOE Emergency Orders

Plant	State	Capacity	Planned Retirement	Status	Order Period
J.H. Campbell	MI	1,331 MW	May 31, 2025	● DOE §202(c) Active	Feb 17–May 18, 2026
Gibson (Units 1–3)	IN	~1,500 MW	Dec 2025	● Order Expired — Retired	Expired Mar 23, 2026
Craig Station (Unit 1)	CO	~430 MW	Dec 31, 2025	● DOE §202(c) Active	Extended Mar 30 — through Jun 2026
Centralia	WA	~660 MW	Dec 31, 2025	● Order Expired — Retired	Expired Mar 16, 2026
Brandon Shores	MD	1,273 MW	Jun 2025	● Deferral Under Negotiation	Ongoing
Intermountain Power Project	UT	1,800 MW	Jul 2025	● Retired as Scheduled	Replaced by 840 MW CCGT
Cumberland (Unit 2)	TN	1,231 MW	2026	● Planned 2026 — No Deferral Order	Largest 2026 planned retirement
Homer City	PA	612 MW	2024	● Retired 2024	—
Schahfer (Units 17–18)	IN	847 MW	Dec 2025	● DOE §202(c) Active	Mar 24–Jun 21, 2026 (Order 202-26-19)
F.B. Culley (Unit 2)	IN	104 MW	Dec 2025	● DOE §202(c) Active	Mar 24–Jun 21, 2026 (Order 202-26-20)
Sources: DOE.gov, Power Magazine, Utility Dive, Colorado Sun, EIA (2025–2026). † Gibson & Centralia DOE orders expired Mar 2026. Schahfer & Culley orders issued Mar 23, 2026.

YE 2025 Stockpiles: 109 MMst (Better Than Forecast)Electric power coal stockpiles ended 2025 at 109 MMst — above the EIA STEO forecast of ~100 MMst and better than feared following Q1 2025 cold-weather drawdowns. Jan 2026 stockpiles fell to 104 MMst (▼5% MoM) on winter drawdowns. Q1 2026 cold weather and elevated gas prices (~$4.76/MMBtu) are driving renewed drawdown. EIA STEO (March 2026) forecasts YE 2026 near 95 MMst. Bituminous days of burn at ~130 days (Jan 2026).

EP Stockpiles (YE 2024)

128 MMst

▼ 2.7% from YE 2023 (131.5 MMst)

Days of Burn (Bitu., Jan 2026)

130 days

▼ from 131 days in Dec 2025

YE 2025 Actual (EIA)

109 MMst

▲ vs. STEO forecast ~100 MMst • EIA Feb 2026

YE 2026 Forecast (STEO)

~95 MMst

EIA March 2026 STEO • Lowest since ~2013

Electric Power Sector Year-End Stockpiles (MMst)EIA · reference

Estimated Days of Burn (Annual Average)EIA · reference

Annual Stockpile Summary

Year	YE Stockpiles	YoY Chg	Days of Burn	EP Consumption	Notes
2015	185 MMst	—	95d	718 MMst	Ample supply
2016	192 MMst	▲3.8%	102d	687 MMst	Warm weather, low burn
2017	175 MMst	▼8.9%	98d	662 MMst	Drawdown begins
2018	157 MMst	▼10.3%	89d	679 MMst	Higher consumption
2019	145 MMst	▼7.6%	85d	583 MMst	Gas price competition
2020	193 MMst	▲33.1%	130d	427 MMst	COVID demand crash
2021	145 MMst	▼24.9%	85d	498 MMst	Strong rebound burn
2022	119 MMst	▼17.9%	70d	507 MMst	High energy prices, max dispatch
2023	141 MMst	▲18.5%	98d	384 MMst	Low gas prices, coal displaced
2024	128 MMst	▼9.2%	110d	373 MMst	Moderate consumption
2025	109 MMst	▼14.8%	~105d	~414 MMst	EIA actual (Feb 2026 release) • Better than forecast
2026F	~95 MMst	▼12.8%	100d	~413 MMst	EIA STEO Mar 2026 • -6% from 2025

HH Annual Avg (2025)

$3.53/MMBtu

▲ 60% from 2024 record low $2.21

HH Q1 2026 (Est.)

$4.80/MMBtu

Jan $7.72; Feb $3.62; Mar ~$3.05 • Apr spot $2.79 (6-mo low)

Coal Gen Share (2025)

~17%

Flat vs 2024 • EIA STEO Mar 2026

U.S. LNG Exports (2024)

11.9 Bcf/d

▲ to ~13.5 Bcf/d in 2025 • #1 globally

PRB Switching Threshold

~$3.00

Henry Hub level where PRB coal competes with gas in Midwest/Southeast dispatch

Illinois Basin Threshold

~$3.50

ILB bituminous becomes broadly competitive vs gas across Eastern markets

Appalachian Threshold

~$4.00

APP coal competes across full Eastern U.S. at this Henry Hub level

Strong Coal Advantage

≥$4.50

Sustained HH ≥$4.50 drives maximum coal dispatch nationally

Henry Hub vs Delivered-to-Power Gas ($/MMBtu)EIA

Quarterly Henry Hub Price ($/MMBtu)EIA

Generation Share by Fuel (%)EIA · reference

Coal vs Natural Gas Generation (TWh)EIA · reference

Annual Fuel Switching Data

Year	HH Avg	Deliv Gas	Coal Gen	Gas Gen	Coal %	Gas %	LNG Bcf/d	Signal
2015	$2.62	$3.40	1,350 TWh	1,332 TWh	33%	33%	0.5	Neutral
2016	$2.62	$3.35	1,240 TWh	1,383 TWh	30%	34%	0.5	Gas Favored
2017	$3.11	$3.87	1,210 TWh	1,275 TWh	30%	32%	1.9	Near Neutral
2018	$3.16	$3.95	1,145 TWh	1,468 TWh	27%	35%	3.0	Gas Growing
2019	$2.56	$3.30	966 TWh	1,578 TWh	23%	38%	4.7	Gas Dominant
2020	$2.03	$2.78	774 TWh	1,617 TWh	19%	40%	6.5	Gas Dominant
2021	$3.84	$4.55	897 TWh	1,576 TWh	23%	37%	9.5	Coal Rebound
2022	$6.36	$7.20	900 TWh	1,690 TWh	20%	39%	11.2	Max Dispatch
2023	$2.53	$3.25	676 TWh	1,799 TWh	17%	43%	11.8	Gas Dominant
2024	$2.21	$2.95	720 TWh	1,820 TWh	16%	43%	11.9	Gas Dominant
2025	$3.53	$4.28	814 TWh	1,718 TWh	17%	40%	13.5	Coal Favored
2026F	$3.76	$4.55	757 TWh	1,693 TWh	15%	38%	15.0	PRB Competitive

Gas Price Scenario Analysis — PRB Demand Sensitivity

Current STEO forecast: $3.76/MMBtu (highlighted). Each $0.50 move shifts PRB demand ~10–15 Mst.

Demand Sensitivity

Scenario Detail

HH Price	Region	Gen (TWh)	PRB (Mst)	Signal
$2.50	None — Gas dominant	650	160	Weak
$3.00	Midwest / Plains	720	180	Moderate
$3.50	+ Illinois Basin	800	195	Solid
$3.80 ◄	Broad Dispatch	757	190	Reference
$4.00	+ Appalachian	850	205	Strong
$4.50	Strong Advantage	900	215	Max
$5.00+	Maximum Coal	950	225	Ceiling
Fuel-switching thresholds: PRB $3.00, ILB $3.50, APP $4.00. Source: EIA STEO Mar 2026.

Snapshot pricing — the comparison table, 52-week charts, and the PRB Market Commentary on this view are a manually-curated Apr 4, 2026 snapshot. They do not auto-refresh. For live Henry Hub use Home or the Daily Pulse.

Weekly Price Comparison — snapshot Apr 4, 2026

Commodity	Week Close	Prior Week	WoW Δ	YTD Open	YTD Δ	Prior Mo	Mo Δ	52-Wk Avg	52-Wk Δ	Source
PRB 8800	$15.00	$15.00	—	$15.00	—	$15.00	—	$14.20	+$0.80	Platts
PRB 8400	$12.15	$12.15	—	$12.15	—	$12.25	-$0.10	$11.75	+$0.40	Platts
AUS 6000 NAR	$135.88	$139.30	-$3.42	$105.75	+$30.13	$108.73	+$27.15	$129.27	+$6.61	IHS McCloskey
IND 4700 NAR	$74.56	$73.85	+$0.71	$60.49	+$14.07	$64.11	+$10.45	$72.55	+$2.01	IHS McCloskey
Henry Hub NG	$2.79	$2.82	-$0.03	$3.62	-$0.83	$5.34	-$2.55	$3.75	-$0.96	ICE
WTI Crude	$111.54	$102.85	+$8.69	$57.32	+$54.22	$60.14	+$51.40	$69.46	+$42.08	ICE

PRB Spot Prices — 52 Week ($/ton)Argus Apr 3

Henry Hub Natural Gas — 52 Week ($/MMBtu)CME Apr 3

International Thermal Coal — 52 Week ($/mt)ICE Apr 3

WTI Crude Oil — 52 Week ($/bbl)CME Apr 3

PRB Market Commentary

PRB 8800: Holding flat at $15.00/ton for ~10 consecutive weeks. This represents a $0.80 premium vs the 52-week average ($14.20). Demand remains stable but not enough to move prompt pricing.

PRB 8400: Steady at $12.15/ton. Slight softness from $12.25 in early Dec. The 8800/8400 spread sits at $2.85/ton, consistent with historical norms.

Gas switching: Henry Hub fell to $2.79/MMBtu (6-month low, -8.5% WoW from $3.05), now well below the ~$3.00 PRB switching threshold. Gas is increasingly competitive with coal for baseload generation at these levels. Mild spring weather easing demand; monitor for rebound as summer approaches.

International Coal & Energy Context

AUS 6000 NAR: $135.88/mt, continued pullback from $139.30 last week and $146.00 geopolitical rally high. Still up +28.5% from $105.75 YTD open. Qatar LNG disruptions continuing but retracement deepening as markets digest. Relevant for NTEC Spring Creek export pricing.

IND 4700 NAR: $74.56/mt, up $14.07 YTD (+23.3%). Indonesian thermal coal tracking the same Pacific tightness.

WTI Crude: $111.54/bbl, up $54.22 from $57.32 YTD open (+94.6%). Energy complex broadly bullish; supports coal competitiveness as overall energy costs rise.

Sources: Platts (PRB Prompt Quarter) • IHS McCloskey (International Coal) • ICE Commodity Exchange (NG, WTI) • ICAP/Coaldesk (PRB Weekly) • Updated weekly from NTEC Weekly Pricing Update

Economic Indicators FRED

Heating & Cooling Degree Days — Coal Demand DriverPopulation-weighted U.S. degree days strongly correlate with coal-fired generation dispatch. The 2025–2026 winter was significantly colder than normal, driving elevated coal burn and stockpile drawdowns. Jan 2026 HDD was 36% above normal — the highest in over a decade.

Reference data — HDD/CDD KPI tiles and the monthly summary table run through Mar 2026 (no live NOAA connector yet). The two charts above the table do refresh from the analytics endpoint.

Jan 2026 HDD

1,385

▲ 36.4% above normal (1,015) · reference

Q1 2026 HDD (Est.)

3,051

▲ ~30% above 30-yr normal · reference

2024 Annual HDD

3,789

▼ 16% below normal • Mild year · reference

Correlation to Coal Gen

~0.82

HDD–to–coal dispatch R² · reference

Monthly HDD — Actual vs Normal (Jan 2024 – Mar 2026)NOAA/EIA

Monthly CDD — Actual vs Normal (Jan 2024 – Mar 2026)NOAA/EIA

HDD Deviation from Normal — Coal Demand Signal

Monthly Degree Day Summary (Jan 2024 – Mar 2026)

Month	HDD Actual	HDD Normal	HDD Dev %	CDD Actual	CDD Normal	CDD Dev %	Signal
Jan 2024	876	1,015	-13.7%	0	0	—	Mild — below-avg coal demand
Apr 2024	298	415	-28.2%	42	85	-50.6%	Very mild spring
Jul 2024	0	5	—	392	425	-7.8%	Summer near normal
Oct 2024	285	425	-32.9%	52	68	-23.5%	Mild autumn
Jan 2025	1,045	1,015	+3.0%	0	0	—	Near normal — shift begins
Jul 2025	0	5	—	445	425	+4.7%	Warm summer — peak CDD
Oct 2025	492	425	+15.8%	28	68	-58.8%	Cold pattern establishing
Dec 2025	1,165	1,006	+15.8%	0	0	—	Major cold setup
Jan 2026	1,385	1,015	+36.4%	0	0	—	Extreme cold — HH to $7.72
Feb 2026	1,154	875	+31.9%	0	0	—	Sustained — stockpile draw
Mar 2026	512	715	-28.4%	18	20	-10.0%	Moderating — still elevated YTD
Sources: NOAA Climate Prediction Center • Population-weighted U.S. national figures • 30-year normals (1991–2020). Updated Mar 31, 2026.

NOAA CPC Outlook Maps CPC

Above-normal temp probability in summer = AC load surge; below-normal in winter = heating demand surge. Both pull coal generation. Maps embed live from cpc.ncep.noaa.gov; click any image to open the source page.

Weather at NTEC Mines & Customer Plants

Site	Type	Now °F	Wind mph	7-day High	7-day Low	Max Precip%

Drought Severity (State, this week)

State	D0	D1	D2	D3	D4	Valid

D0 = abnormally dry · D4 = exceptional drought. Drought reduces hydro → flips marginal generation to thermal.

Active Severe / Extreme Weather Alerts (NWS)

Market Fundamentals — EIA Live FeedNG storage, STEO 18-month forecasts, RTO daily fuel-mix. Refreshed 3×/day weekdays from the EIA API.

U.S. Natural Gas Working Storage (Lower 48) —

Weekly Bcf of working gas in underground storage. The single most-watched weekly number in the energy complex — big surprises here move NG prices, which directly drive coal demand.

Coal Share of U.S. Electricity Generation —

EIA STEO forecast. Dashed portion is forward projection. Useful for projecting coal demand envelope vs. gas/renewables.

Henry Hub Natural Gas Price — STEO Forecast

$/MMBtu. Solid = historical actuals; dashed = STEO projection.

Coal Price Delivered to Electric Power

$/MMBtu delivered cost. STEO monthly average.

U.S. Coal Production vs. Electric Power Consumption

Million short tons/month. When consumption > production, stockpiles draw down.

Western Region Coal Production (PRB & adjacent)

MMst/month. PRB is the dominant piece of Western Region output.

Daily Coal vs. Natural Gas Generation — MISO / SPP / PJM

Daily MWh by ISO & fuel. When coal rises relative to gas, plants are dispatching coal — a real-time sign of coal demand health.

STEO Forecast Snapshot — Key Series

Metric	Latest Actual	+3 mo	+12 mo	+24 mo	Unit
Loading STEO data…

Train Loading Analytics — Last 90 Days

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Coal vs. Gas Dispatch — Observed Switching

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Coal Quality Compliance

Weighted average quality metrics (ASH, BTU, Moisture, Sulfur) by mine and customer. Source: CMS shipment data.

Tonnage-weighted monthly averages by mine.

BTU Trend by Mine

Sulfur Trend by Mine

Ash Trend by Mine

Moisture Trend by Mine

Sodium Trend by Mine

SO₂ Trend by Mine

Quality by Customer (Last 90 Days)

Customer	Mine	Ships	Avg BTU	Avg Ash %	Avg Moisture %	Avg Sulfur %	Avg SO2	BTU StdDev
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Slot Plan Execution

Compares scheduled slot times to actual CMS loading. Measures planning accuracy and identifies systemic delays.

Slot Match Rate by Mine

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Recent Slot Matches (Scheduled vs Actual)

Mine	Slot Time	Train	Outbound	Actual Load Start	Delta (hrs)	Status
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Missed Opportunities

Trains that appeared on the slot plan but never shipped in CMS. Identifies lost tonnage potential and patterns by mine and time period.

Date range From To

Monthly Miss Rate

Miss Rate by Mine

Recent Missed Trains

Slot Date	Mine	Train ID	Outbound	Status
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Railroad Nominations

Live mirror of Nominations-Railroad.xlsx on SharePoint. Working month is the latest month with non-zero totals — sales is editing it now. Budget figures source from the Basefile sheet (history back to 2023).

By Mine — Working Month

Mine	Budget	UP	BNSF	Total Noms	Log Fcst	% of Budget	vs Budget
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Coverage vs Budget — Working Month

Monthly Trend — Budget · Nominations · Actual Shipped

Working-Month Detail

Mine	Customer	Plant	Contract #	Sales Rep	UP	BNSF	Total	Log Fcst	Diff	Comments
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End-of-Month Forecast Report

Mirror of the EOM Forecast Report sheet — current-month nominations, railroad split, month-over-month change, and YTD performance, all in one view.

Nomination Summary

Mine	Budget	UP Noms	BNSF Noms	Total Noms	Log Forecast	Nom % of Budget	Variance
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Railroad Breakdown

Mine	UP Noms	UP %	BNSF Noms	BNSF %	Total	Contracts
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Month-over-Month Comparison

Mine	Current	Prior	MoM Δ Tons	MoM Δ %	Budget Δ %	Contracts Δ
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Year-to-Date Performance

Mine	YTD Budget	YTD Noms	YTD Variance	YTD Var %	YTD Log Fcst	Avg Monthly	Months Rptd
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Customer Concentration Risk

Revenue concentration analysis — identifies dependency on top customers and contract expiry risk.

YTD Tons by Customer (Top 15)

Cumulative Concentration Curve

Top 20 Customers — YTD Detail

Customer	YTD Trains	YTD Tons	Share %	Cumul %	Mines	PY Tons	YoY %
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Contract vs Actual Variance

Compares contracted annual tons to actual YTD shipments. Highlights contracts ahead or behind pace.

Contract Pace — YTD

Mine	Contract	Customer	Annual Tons	YTD Actual	Trains	Pace %	Expected %	Variance
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Contract Intelligence

Detailed contract terms extracted from actual contract documents — pricing schedules, quality specs, volumes, and delivery terms. One-time load from contract analysis.

Contract Details

Contract #	Customer	Mine	Type	Effective	Expiration	Volume	Price	Quality Spec
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Weather & Demand Correlation

How heating/cooling degree days drive coal demand and NTEC shipments. Source: NOAA + EIA + CMS.

HDD vs NTEC Tons (Monthly)

Degree Days vs Coal Consumption

Mine Safety & Compliance — MSHA DataViolations, inspections, incidents, and quarterly production for Antelope (ACC), Cordero Rojo (CMC), and Spring Creek (SCC). Source: MSHA Open Government Data, updated weekly.

Violations (3yr)

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S&S Violations (3yr)

—

Significant & Substantial

Total Penalties (3yr)

—

Proposed penalties

Incidents (3yr)

—

Days Since Last Incident

—

Most recent across NTEC mines (MSHA)

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Recent Violations — Last 10

Date	Mine	Violation	Section	S&S	Penalty	Status
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Source: MSHA Open Government Data (arlweb.msha.gov). Violations, inspections, accidents from MSHA enforcement records. Updated weekly (Fridays).

SCC Export Operations Export shipments via Spring Creek to Roberts Bank / Westshore. Source: CMS + WLU + BNSF.

MTD Trains

—

Month-to-date

MTD Tons

—

Month-to-date

YTD Annualized Pace

—

On pace for the full year

YTD Trains

—

Year-to-date

Monthly Export Trains Last 24 months · CMS

Monthly Export Tons Last 24 months · CMS

Export Contracts

Mine	Contract	Customer	FOB	Type	Start	End	Tons	Trains	Notes
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Vessel Schedule

Vessel GANTT Timeline

Vessel Schedule

Vessel	Customer	Laydate	ETA	ETB	ETD	Trains	MT Tonnage	Price Fixed	Executed
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Rail Lineup & Cycle Time

Shipment-level detail from WLU Rail Lineup + export cycle time (loaded/empty days).

Export Cycle Time (Loaded → Unloaded) Last 30 trains

Recent Rail Shipments (Loaded) Most recent 50 · WLU rail lineup

Shipment	Vessel	Customer	Loaded	Unloaded	Short Tons	MT
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Train Plan & In Transit

Train Plan — Monthly (Planned vs Loaded) Full plan horizon · WLU

Train Plan Detail Full plan horizon

Month	Planned	Loaded	Remaining	Rate/Day
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Trains In Transit — BNSF Customer API (LIVE)Real-time positions of NTEC coal trains on the BNSF network.

Active Train Positions — —

Status	Train	Origin	Current Location	Last Event	Cars	Destination	ETA	Event Age
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New (first seen <24h, pre-Pasco) · In Transit (active >24h, pre-Pasco) · Primed (past Pasco) · Missed (past Pasco >48h) · Dumped (placed at terminal)

Train Map — Live GPS Positions

Demurrage

Vessel demurrage, despatch, and cost tracking from WLU.

Scope: YTD 2026

Demurrage Detail —

Date	Customer	Contract	Ship	Dem/Day	Demurrage	Despatch	Tonnes	Status
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Daily Pulse

NTEC ATLAS · Logistics summary

NTEC ATLAS

—

Confidential

Daily Pulse

Shipped Yesterday

—

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Currently Loading

—

CMS TrainStatus (live)

SCC Export In Transit

—

BNSF Customer API

Henry Hub NG

—

Yesterday's Customers

Customer	Mines	Trains	Tons
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Mine Status — Today

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Data Health

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Week in Review

NTEC ATLAS · Weekly briefing

NTEC ATLAS

—

Confidential

Week in Review

Trains This Week

—

Tons This Week

—

Customers Served

—

Distinct count

Henry Hub NG

—

Coal Gen Share

—

EIA STEO latest

SCC Export Deliveries

—

Placed at Westshore

Shipment Breakdown by Mine

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Customer Activity This Week

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Carrier Performance (MTD)

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Contract Coverage

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Monthly Executive Summary

NTEC ATLAS · Production, plan, and forward book

NTEC ATLAS

—

Confidential · Internal use

Monthly Executive Summary

MTD Trains + Tons

—

Annualized Pace

—

Pace vs Plan

—

43M ton target

Coal Gen Share

—

NG Price Trend

—

Active Contracts

—

Production Pace by Mine — MTD vs Plan

Top Customers MTD

Customer	Mines	Trains	Tons
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STEO Forecast Snapshot

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Contract Coverage

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Upcoming Expirations (90 days)

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NTEC Contracted Tons — Sales & Marketing Intelligence (CONFIDENTIAL)Data sourced from Main Table (SharePoint, last updated Mar 27, 2026). Includes all firm and flex tons across 2026–2029. Committed & priced (firm) tons shown separately. Revenue based on fixed-price contracts only. Contract Details & Alerts sub-tab updates monthly.

Snapshot view — KPIs, contract list, and forward-book tables on this tab are a manually-maintained snapshot dated Mar 27, 2026. They do not auto-refresh. Live CMS-derived counts are on the Customer Sales and Contract Intelligence tabs.

Contract Expiration Waterfall — Revenue Cliff

Active contracts by expiration year. Shows when contracted tons drop off and what needs renewal.

Contracted Tons — 2026

42.9 M tons

Firm + flex • as of Mar 27, 2026

2026 Est. Revenue (Projected)

$948.3M

Estimate based on contract pricing — not invoiced revenue

Contracted Tons — 2027

25.1 M tons

▼ 41.6% drop-off from 2026 — tons at risk if not renewed

Active Contracts

52

As of Mar 27, 2026 • FOB, Delivered & Export

Domestic FOB Mine (2026)

~35.0 M tons

~81% of total book

Domestic Delivered (2026)

~3.5 M tons

~8% of total book

Export — JERA (2026)

~2.4 M tons

Spring Creek • Premium price

Export — Non-JERA (2026)

~3.7 M tons

KOMIPO, KOEN, KOWEPO, KOSPO + others

Blended Avg Price (2026)

$13.92/ton

ACM $14.29 • CRD $11.06 • SCM $15.95

Highest Contract Price

$15.25/st

DTE #2959 carryover

Lowest Contract Price

$11.06/st

CRD domestic FOB blended

Open Flex Options

3

DTE +500K • NRG +20% • NRG defer 20%

Critical Alerts

3

Deadlines within 90 days

Warnings

5

Action needed in 2026

Opportunities

5

Volume upside & new contracts

Plant Risks

3

Customer plant conversion/retirement

Forward Book by Mine — All Tons (ktons)Contracts Apr 1

Saved!

2026 Sales Position — Budget vs. Committed (ktons)Contracts Apr 1

Projected Revenue & Avg Realized Price by MineContracts Apr 1

Book Coverage — Contracted Tons by Expiration YearContracts Apr 1

NTEC Contracted Tons Summary — 2026–2029 (as of Mar 27, 2026)

Mine	Type	2026 (M tons)	2027 (M tons)	2028 (M tons)	2029 (M tons)	2026 Est. Rev ($M)*	2026 Avg $/ton*
Antelope	All	21.5	16.6	7.5	1.6	$283.6	$14.29
Cordero Rojo	All	13.8	6.1	1.7	2.3	$152.6	$11.06
Spring Creek	All	7.6	2.3	0.9	0.8	$248.6	$15.95†
NTEC Total		42.9	25.1	10.1	4.7	$684.8	$13.92
* Revenue and $/ton are estimated projections based on contracted tons × fixed pricing per contract terms — not invoiced or realized revenue. Actual revenue will vary with shipment timing, quality adjustments, and flex-ton execution. † SCM avg price reflects domestic FOB only; export tons (~$86/ton) excluded from blended calc. Source: Main Table (SharePoint) • Snapshot as of Mar 27, 2026.

Contracted Tons Coverage Gap — Open Position by Mine & Year

2027 open position: 17.9M tons (41.7%) — primary sales priority. By 2029, only 11.0% contracted.

Year

Sales Plan Target (M tons)**

Contracted

Open Position

Coverage %

Status

2026

43.0

42.9

0.1

99.8%

Fully Covered

▼

2027

43.0

25.1

17.9

58.3%

Major Gap

▼

2028

43.0

10.1

32.9

23.5%

Largely Open

▼

2029

43.0

4.7

38.3

11.0%

Essentially Open

▼

** Sales Plan Target = 2026 executive plan (43M tons/year: ACM 19M + CRD 14.5M + SCM 9.5M). This is an internal sales target used for coverage analysis, not a production forecast or committed budget. 2027+ targets use the same baseline for planning.
Source: NTEC Main Table (SharePoint), snapshot as of Mar 27, 2026. Click any year row to expand mine detail. Coverage includes firm + flex tons.

Antelope (ACM) — Forward Tons by Year (ktons)

Mine	Customer Type	2026	2027	2028	2029
Antelope	Domestic FOB Mine	21,509	16,601	7,480	1,600
Cordero Rojo	Domestic FOB Mine	13,806	6,117	1,698	2,300
Spring Creek	Domestic FOB Mine	4,172	2,211	811	811
	Domestic Delivered	144	135	135	—
	Export (non-JERA)	3,139	—	—	—
	Other / Unallocated	165	—	—	—
Grand Total		42,935	25,064	10,124	4,711
Source: Main Table pivot — Sold To tab. Mar 27, 2026. JERA export deal expired in 2025. Non-JERA export book runs through 2026 only.

Avg Realized Price by Mine — 2026 ($/ton)

Contract-Specific IntelligenceUnique terms extracted from individual contracts including pricing escalators, flex/carryover provisions, nomination deadlines, diesel fuel clauses, and quality contingencies. Last full refresh: March 26, 2026. Source: Summary Domestic Coal Contractual Obligations & Master Agreements Log.

All Active Contracts (as of Mar 26, 2026 — 54 records at time of snapshot)

Contract ◆	Customer ◆	Mine ◆	Tons ◆	Expires ◆	Pricing / Notes	Flags
#2957	ADM (Archer Daniels Midland)	ACM	1.0M	Dec-25	$13.85/ton (CY25); carryover $14.10/ton (CY26)	COOB
#2942	Alabama Power	ACM	100K	Dec-27	—
#2975	Alabama Power	ACM	5.0M	Dec-28	—	COOB
#3059	Alliant Energy (Interstate Power...	ACM	1.5M	Dec-29	Escalating (pricing table in PDF partially extracted); Bt...	COOB
#2962	Ameren	ACM	5.0M	Dec-28	$13.82-$14.85/ton escalation	COOB
#2987CO	Ameren	ACM	175K	Dec-26	$13.35/ton	COOB
#3050 Expiring	Avanza Trading LLC	ACM	32K	Mar-26	$15.00/ton; pre-payment required	OB
#3007	Cemex	ACM	100K	Dec-26	—	OB
#3041	Colorado Springs Utilities (CSU)	ACM	392K	Dec-26	$14.75/ton; 8900 Btu product; carryover at $15.10	COOB
#3011	Georgia Power	ACM	582K	Dec-27	—	COOB
#2997	LCRA	ACM	150K	Sep-26	$13.20/ton carryover	COOB
#2926	Omaha Public Power District	ACM	2.0M	Dec-26	—	COOB
#2861	PRPA	ACM	7.7M	Dec-30	—	OB
#3009	Plum Point (East Texas Electric ...	ACM	600K	Dec-26	$13.65/ton; Btu adj @ 8900 BB; SO2 0.52 lb/mmBtu; ash rej...	OB
#3060 Draft	Plum Point (East Texas Electric ...	ACM	900K	Dec-27	$15.15/ton; Btu adj @ 8900 BB; SO2 0.52 lb/mmBtu; ash rej...	OB
#3004	Tennessee Valley Authority (TVA)	ACM	5.8M	Dec-27	$13.42 (Apr-Dec25); $13.60 (CY26); $13.83 (CY27) per ton;...	COOB
#3036	WE Energies WEPCO	ACM	200K	Dec-27	—	OB
#2826	We Energies	ACM	100K	Dec-26	—	OB
#2911	Western Fuels	ACM	120K	Dec-26	—	COOB
#2954	Western Fuels Association (Holco...	ACM	200K	Dec-26	$14.25/ton; 8900 Btu product	COOB
#2995	Western Fuels Association (Nearm...	ACM	1.2M	Dec-27	$13.25 (CY25); $13.45 (CY26); $13.63 (CY27) per ton; 8900...	OB
#3037	Wisconsin Public Service	ACM	125K	Dec-26	—	OB
#2941	Alabama Power	CRD	200K	Dec-27	—	COOB
#2982	Alabama Power	CRD	500K	Dec-28	—	COOB
#3020	Alliant	CRD	800K	Dec-28	—	COOB
#3058	Alliant Energy (Interstate Power...	CRD	1.5M	Dec-29	$11.35 (CY27); $11.55 (CY28); $11.75 (CY29) per ton	COOB
#2976	CPS City of San Antonio	CRD	9.5M	Dec-27	—	COOB
#2991	Evergy	CRD	500K	Dec-26	—	COOB
#2998	Evergy	CRD	2.8M	Dec-28	$13.20-$14.25 escalation	COOB
#2974	Georgia Power	CRD	1.2M	Dec-27	55-day trestle outage Oct 2025	COOB
#3010	Georgia Power	CRD	1.1M	Dec-28	—	COOB
#2978	LCRA	CRD	5.0M	Dec-28	—	COOB
#2948	Luminant	CRD	1.0M	Dec-26	—
#2999	NRG	CRD	3.0M	Dec-26	—	COOB
#3021	Nebraska Public Power District	CRD	7K	Dec-32	—	OB
#2927	Omaha Public Power District	CRD	2.0M	Dec-26	—	COOB
#2968	Otter Tail Power	CRD	3.0M	Dec-26	—	OB
#2938	Plum Point	CRD	600K	Dec-26	—	COOB
#NT700 BUY	Global Coal Sales Group LLC	N/A (Pur	4K	Dec-25	$60.00/metric tonne; DAP Westshore Terminals	OB
#2782	American Crystal Sugar	SCM	6.6M	Jul-31	—	OB
#2780	DTE Electric Company	SCM	11.4M	Dec-30	—	OB
#3046 Expiring EXP	JERA Co. (Japan)	SCM	83K	Mar-26	Periodic pricing - see confirmation	OB
#3057 EXP	JERA Co. (Japan)	SCM	83K	Jun-26	Periodic pricing - see confirmation	OB
#3064 EXP	JERA Co. (Japan)	SCM	83K	Jul-26	$15.56/ton; ash quality adjustment formula	OB
#3065 EXP	KOEN (Korea South-East Power Co.)	SCM	1.1M	Dec-26	$15.56/ton; 9350 Btu; 0.8 SO2; 6.0% ash typical	OB
#3061 EXP	KOMIPO (Korea Midland Power Co.)	SCM	446K	Aug-26	$15.56/ton; 9350 Btu; 0.8 SO2; 6.0% ash typical	OB
#3062 EXP	KOMIPO (Korea Midland Power Co.)	SCM	446K	Dec-26	$15.56/ton; 9350 Btu; 0.8 SO2; 6.0% ash typical	OB
#3063 EXP	KOWEPO (Korea Western Power Co.)	SCM	176K	May-26	$15.56/ton; 9350 Btu; 0.35 SO2; 6.0% ash typical	OB
#KOSPO-ELT07 EXP	Korea Southern Power Co. (KOSPO)	SCM	—	TBD	Scanned PDF - pricing not extractable; needs manual review	OB
#2971	Minnesota Power	SCM	2.8M	Dec-27	$15.55 (CY26); $16.10 (CY27) per ton	OB
#3032 EXP	Mitsubishi Corp RtM Japan (for J...	SCM	—	Jun-26	See agreement terms; extended period confirmed 3/25/2026	OB
#N0253	NDSU	SCM	54K	Jun-26	—	OB
#3038	Salt River Project (SRP)	SCM	400K	Dec-26	$15.50/ton; +200K flex option	OB
#2898	Wolf Mountain	SCM	270K	May-26	—	OB

Source: Summary Domestic Coal Contractual Obligations & Master Agreements Log. Mar 27, 2026. Click column headers to sort. Use mine filters above to narrow view.

Flex & Carryover Options

Customer	Option Type	Volume	Deadline	Price
DTE #2959	Flex Up	+500K tons	Nov 1, 2026	$14.70/st
NRG #2999	Flex Up	+20%	Jun 30, 2026	Contract price
NRG #2999	Deferral	20% → 2027	Dec 31, 2026	Contract price
Plum Pt #2938	Carryover	Per terms	—	$14.80 ('25→'26)
Plum Pt #2938	Carryover	Per terms	—	$15.10 ('26→'27)
LCRA	Carryover	Per terms	—	$11.35
Ameren #2987CO	Carryover	175K tons	Exercised	$13.35 (done 9/11/25)
CSU #3041	Carryover	30% to 2027	Per terms	$15.10 ('26→'27)
Alliant #3058	CO/Pull-Fwd	20%/30%	End Q4/Q1	CRD $11.35-11.75
Alliant #3059	CO/Pull-Fwd	20%/30%	End Q4/Q1	ACM escalating; CY29 CO $15.30
SRP #3038	Flex Up	+200K tons	Aug 1, 2026	$15.50/st

Special Provisions & Clauses

Customer	Provision	Details
Alabama Power #2941	Quality Contingency	If Plant Miller has issues with CRD coal, volumes reallocate from CRD to ACM
CPS Energy #2976	Requirements Contract	100% of CPS plant needs; CY25: 2.5M, CY26: 3M, CY27: 4M tons
Wolf Mtn #2898	Liquidated Damages	LDs triggered if shipment period volume < 50K tons
TVA #2755	Volume Flex	3.5mt total confirm; ±20% per year flexibility
Multiple	Diesel Fuel	Several contracts have diesel fuel price reopener clauses
All Contracts	Assignment	Assigned through bankruptcy court 10/24/2019 to NTEC

Master Agreement Terms

Customer	Payment Terms	Termination	Entity
Most Customers	Semi-monthly net 10/12/15	On 60 days notice	NTEC
OPPD	Per standalone agreement	Term agreement eff. 1/1/2024	NTEC
Export (JERA)	Per train	Per confirm	NTEC
Select Domestic	Weekly	On 60 days notice	NTEC

Wolf Mountain #2898 — Pricing Renegotiation MeetingCritical

Meeting required by April 1, 2026 to discuss pricing for Jun 2026–May 2027 period. LDs apply if shipment period volume falls below 50K tons. Prepare pricing position and volume commitments. SCM

Deadline: April 1, 2026 (6 days away)

NRG #2999 — Volume Increase Option DeadlineCritical

Option to increase 2026 volumes by 20% expires June 30, 2026. Evaluate demand signals and pricing before deciding. Separate option to defer 20% into 2027 by Dec 31, 2026. ACM CRD

Deadline: June 30, 2026 (~96 days away)

DTE Energy #2959 — Additional Volume OptionCritical

Option for additional 500K tons at $14.70/st must be exercised by November 1, 2026. Carryover priced at $15.25/st. DTE Belle River plant converting to gas — monitor impact on future demand. ACM

Deadline: November 1, 2026 (~220 days away)

NRG #2999 — Deferral Option WindowWarning

Can defer 20% of 2026 committed volumes into 2027 if exercised by December 31, 2026. Track actual shipment pace vs. plan to evaluate. ACM CRD

Deadline: December 31, 2026

DTE Belle River — Gas Conversion RiskWarning

DTE Energy's Belle River plant is converting from coal to natural gas. This directly impacts future coal demand from DTE. Current contract (#2959) runs through 2027 but post-conversion volumes will likely go to zero. Evaluate replacement demand sources. ACM

Ongoing — conversion timeline TBD

TransAlta — Contract ExpiringWarning

TransAlta contract approaching expiration. Assess renewal prospects and alternative customer pipeline for affected volumes. Canadian regulatory environment for coal generation increasingly restrictive.

Expiration: Near-term — confirm exact date

Minnesota Power — Boswell Plant RetirementWarning

Minnesota Power's Boswell Energy Center retirement plan impacts future coal demand. Units being phased out under state clean energy mandate. Track legislative and regulatory developments.

Ongoing — phased retirement per MN clean energy law

Alabama Power #2941 — Quality Contingency ActiveInfo

If Plant Miller experiences quality issues with Cordero Rojo coal, contractual provision shifts volumes from CRD to Antelope mine. Monitor quality reports and any customer communications about coal performance at Miller. ACM CRD

Active provision — triggered by quality events

CPS Energy #2976 — Growing Requirements VolumeOpportunity

Requirements contract guarantees 100% of CPS plant needs. Volumes stepping up: CY25 2.5M → CY26 3.0M → CY27 4.0M tons. Represents growing committed base load. ACM

Increasing through 2027

Diesel Fuel Reopener ClausesOpportunity

Several contracts contain diesel fuel price reopener clauses. With diesel prices elevated, these clauses may allow price adjustments that improve realized margins. Review trigger thresholds across affected contracts.

Active provisions — monitor diesel price vs. thresholds

New Export Book — Korean Utilities (KOMIPO, KOEN, KOWEPO)Opportunity

Three new Korean export contracts signed in March 2026 totaling ~1.7M tons of Spring Creek coal at $15.56/st: KOMIPO #3061/#3062 (~893K tons May-Dec), KOEN #3065 (~1.08M tons Dec), KOWEPO #3063 (~176K tons Apr-May). All at 9350 Btu with standard ash adjustment formula. Strengthens export diversification. SCM

New — March 2026 monthly refresh

Alliant Energy #3058/#3059 — New Multi-Year ContractsOpportunity

Two new 3-year Alliant contracts signed March 2026: #3058 (CRD, 500K/yr CY27-29, $11.35-$11.75 escalating) and #3059 (ACM, ~500K/yr CY27-29, escalating pricing). Both include 20% carryover and 30% pull-forward flexibility. Adds 3M committed tons to the 2027-2029 book. ACM CRD

New — Signed March 10-18, 2026

Avanza Trading #3050 — ExpiredExpired

Avanza Trading contract for 32K tons of Antelope coal expired end of March 2026. Pre-payment required contract. Destination: Cora Coal Terminal. Renewal not in place. ACM

Expired: March 2026

Key Dates Timeline — 2026 Snapshot Mar 27, 2026 · manually maintained

Date	Event	Contract	Action Required	Impact
Apr–May	KOWEPO export shipment (in progress)	#3063	~176K tons SCM Apr 15–May 31	$2.7M export revenue
May–Aug	KOMIPO export shipment	#3061	~446K tons SCM May 15–Aug 31	$6.9M export revenue
Jun 30	NRG volume increase deadline	#2999	Decide on +20% volume option	~500K tons upside
Aug 1	SRP flex volume option	#3038	Decide on +200K tons at $15.50	$3.1M revenue add
Sep–Dec	KOMIPO export shipment	#3062	~446K tons SCM Sep–Dec 2026	$6.9M export revenue
Nov 1	DTE additional volume option	#2959	Exercise 500K tons at $14.70	$7.35M revenue add
Dec	KOEN export shipment	#3065	~1.08M tons SCM Dec 2026	$16.8M export revenue
Dec 31	NRG deferral decision	#2999	Decide on 20% deferral into 2027	Volume shift to '27
Ongoing	Alabama Power quality monitoring	#2941	Track Miller plant coal performance	CRD↔ACM shift risk
Ongoing	Diesel fuel price monitoring	Multiple	Track diesel vs. reopener thresholds	Margin improvement

YTD Shipped (All Mines)

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Active Customers (YTD)

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Top Customer (YTD)

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Avg Train Size

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Contracted vs. Nominated vs. Actual — Working Month

Per-customer view: what they're contracted for in the period, what Sales nominated, and what actually shipped. Coverage = Actual / Contracted. Variance = Actual - Nominated (positive = exceeded the nom).

Customer	Mines	Contracted	Nominated	Actual	Coverage	Act vs Nom	Status
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Contract Utilization — Contracted vs. Shipped (2026)

Per-contract view: 2026 committed tons vs. actual YTD shipments. Tons are allocated to earliest contracts first (waterfall). Pace = shipped ÷ expected-by-now.

Contract	Customer	Mines	2026 Tons	Shipped	Utilization	Pace	Status	$/ton	Expires
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Contract Status Report — YTD Shipments (from CMS)

Customer ◆	Mine	Contract # ◆	YTD Shipped ◆	Ratable (YTD)	Variance ◆	% of Ratable	Status

YTD Shipments by Customer — Top 15 (ktons)

Customer Reliability Scorecard — Top 25 (10-year CMS history)

Customer	Mines	Score	Shipments	Total Tons	12mo Growth	Consistency	Since
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Column guide: Score — overall reliability (0–100) blending volume, consistency & tenure (green ≥80, amber 50–79, red <50). Mines — districts that ship to this customer (ACC/CMC/SCC). Shipments — total CMS shipments over the 10-year history. Total Tons — cumulative tons shipped. 12mo Growth — tonnage change vs. the prior 12 months. Consistency — how steady month-to-month volumes are (higher % = less volatile). Since — date of first recorded shipment.

NTEC & PRB ProductionInternal monthly shipment history alongside MSHA-sourced PRB industry production. NTEC data from monthly Coal Shipments workbook; PRB industry data from MSHA quarterly Form 7000-2 filings. Updated when source workbooks roll forward.

2025 PRB Total

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vs prior year

YTD 2026

…

Through latest month

Q1 2026 vs Q1 2025

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PRB total Q1 change

NTEC Share of PRB

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2025 actual / MSHA total

NTEC Monthly Shipments by Mine

NTEC Annual Production by Mine (k tons)

Q1 Year-over-Year by Mine

NTEC PRB Cumulative (k tons)

PRB Industry Context — MSHA

PRB Total 2025

…

SPRB + NPRB

Top Producer

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M tons 2025

Biggest YoY Mover

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vs 2024

Active PRB Mines

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2025 producers

Top 10 PRB Mines — 2024 vs 2025 (M tons)

PRB Production Long-term Trend (M tons)

PRB Mines Ranking — 2025 Actual (M tons)

Rank	Mine	Owner	State	2024	2025	YoY	YoY %	Share
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NTEC Logistics & Operations — CMS Live Data (CONFIDENTIAL)Data sourced from CMS SQL Server via pyodbc. Includes shipment tracking, budget vs. actual pace, contract status, weekend operations, and coal quality metrics.

Snapshot KPIs — the KPI rows on the sub-tabs below (Customer Sales, Budget vs. Actual, Daily Roundup, Slot Plan, Weekend Report) reflect a manual Apr 5–6, 2026 snapshot and do not auto-refresh. Charts and detail tables further down each sub-tab are live CMS.

Daily Report — loading… (CMS Live Data)

Yesterday’s Activity

	ACC	CMC	SCC	Total
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Month-to-Date

	ACC	CMC	SCC	Total
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Weekly Shipment Detail (CMS Live)

Date	Day	Trains	ACC	CMC	SCC
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CMS Live Pipeline Connecting…

Customers Shipped Yesterday

Customer	Mines	Plants	Trains	Tons
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Top Customers by Mine — last 7 days

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Weekly Customer Activity — last 7 days

Customer	Mines	Trains	Tons
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MTD Run Rate by Mine

Mine	MTD Trains	MTD Shipped	Annualized Pace
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Annualized = (MTD tons / days elapsed) × 365. Derived from CMS shipment history.

Joint Line Performance — MTD

Carrier	MTD Trains	Avg Trains/Day	MTD Tons
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BNSF / UP split from the CarrierCode column in CMS.

Daily Train Loadings \u2014 last 30 days

Daily Tonnage \u2014 last 30 days (ktons)

Weekend Operations Loading most-recent-weekend CMS data…

Weekend Train Counts by Mine & Day

Weekend Tonnage by Mine & Day

Rail Market Intelligence — PRB Coal TransportationWeekly PRB coal unit train loadings and Class I railroad coal carload trends. PRB coal moves almost entirely by BNSF (~60%) and Union Pacific (~40%). Sources: USDA/STB weekly data, AAR weekly rail traffic reports.

Reference data — KPIs, monthly table, and 52-week charts on this view are static reference values through Mar 2026 (no live AAR/STB connector wired). Treat as a directional benchmark, not today's market.

PRB Unit Trains (Latest Wk)

44/week

Week ending Mar 29 • ▲ vs 38 yr ago

PRB Carloads (Latest)

9,680

▲ +12.8% YoY

Total Coal Carloads (AAR)

67,820

Class I • ▲ +8.2% YoY

Coal Share of Rail

25.1%

Of total Class I carloads

PRB Unit Train Loadings — 52 Week (trains/week)AAR Apr 6

Class I Coal Carloads — 52 Week (AAR)

PRB Carloads by Railroad (BNSF vs UP)

Coal Share of Total Rail Carloads (%)AAR Apr 6

PRB Coal Rail Carloadings — Monthly Summary

Month	PRB Trains	PRB Carloads	BNSF	UP	AAR Coal Total
Friday Apr 3	ACC Antelope	2	31,850	15,925	8.9%
	CMC Cordero	3	45,858	15,286	12.8%
	SCC Spring Creek	0	0	—	0%
	SCX Spring Creek Export	3	49,114	16,371	13.7%
Saturday Apr 4	ACC Antelope	3	47,641	15,880	13.3%
	CMC Cordero	1	16,451	16,451	4.6%
	SCC Spring Creek	2	31,398	15,699	8.8%
	SCX Spring Creek Export	1	16,306	16,306	4.6%
Sunday Apr 5	ACC Antelope	4	58,411	14,603	16.3%
	CMC Cordero	1	17,110	17,110	4.8%
	SCC Spring Creek	3	11,248	3,749	3.1%
	SCX Spring Creek Export	2	32,620	16,310	9.1%
Weekend Total		25	358,007	14,320	100%

Heating & Cooling Degree Days — Coal Demand DriverPopulation-weighted U.S. degree days strongly correlate with coal-fired generation dispatch. The 2025–2026 winter was significantly colder than normal, driving elevated coal burn and stockpile drawdowns. Jan 2026 HDD was 36% above normal — the highest in over a decade.

Reference data — KPI tiles and the monthly table run through Mar 2026 only (no live NOAA connector wired here). The HDD/CDD charts above the table refresh from the analytics endpoint. April 2026 actuals are not in the table.

Jan 2026 HDD

1,385

▲ 36.4% above normal (1,015)

Q1 2026 HDD (Est.)

3,051

▲ ~30% above 30-yr normal

2024 Annual HDD

3,789

▼ 16% below normal • Mild year

Correlation to Coal Gen

~0.82

HDD–to–coal dispatch R²

Monthly HDD — Actual vs Normal (Jan 2024 – Mar 2026)

Monthly CDD — Actual vs Normal (Jan 2024 – Mar 2026)

HDD Deviation from Normal — Coal Demand Signal

Monthly Degree Day Summary (Jan 2024 – Mar 2026)

Month	HDD Actual	HDD Normal	HDD Dev %	CDD Actual	CDD Normal	CDD Dev %	Signal
Jan 2024	876	1,015	-13.7%	0	0	—	Mild — below-avg coal demand
Apr 2024	298	415	-28.2%	42	85	-50.6%	Very mild spring
Jul 2024	0	5	—	392	425	-7.8%	Summer near normal
Oct 2024	285	425	-32.9%	52	68	-23.5%	Mild autumn
Jan 2025	1,045	1,015	+3.0%	0	0	—	Near normal — shift begins
Jul 2025	0	5	—	445	425	+4.7%	Warm summer — peak CDD
Oct 2025	492	425	+15.8%	28	68	-58.8%	Cold pattern establishing
Dec 2025	1,165	1,006	+15.8%	0	0	—	Major cold setup
Jan 2026	1,385	1,015	+36.4%	0	0	—	Extreme cold — HH to $7.72
Feb 2026	1,154	875	+31.9%	0	0	—	Sustained — stockpile draw
Mar 2026	512	715	-28.4%	18	20	-10.0%	Moderating — still elevated YTD
Sources: NOAA Climate Prediction Center • Population-weighted U.S. national figures • 30-year normals (1991–2020). Updated Mar 31, 2026.

Slot Plan — Live Railroad Feed (CONFIDENTIAL)Active train assignments from BNSF and UP slot emails, parsed from Power Automate email capture.

Today’s Slot Plan — loading…

Mine	On Site	Loading	With ETA	Later	Departed
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Loading/Departed states are CMS-derived (real-time). On Site / With ETA / Later come from the slot email.

Actively Loading — Live from CMS LOADING

CMS reports these trains as actively loading (arrival logged, loadout open, not yet shipped). Refreshed every 5 minutes from CMS_TrainStatus.

State	Mine	Customer	Train ID	Loco	Outbound ID
No trains actively loading right now.

On Site Now — At Mine

Status	Mine	Customer	Train ID	Loco	Outbound ID
AT MINE	ACC Antelope	Tennessee Valley Authority (Shawnee, KY)	B19	E-PCTATM8-67A	BNSF 5602	C-ATMCLS0-74A
AT MINE	ACC Antelope	Evergy Metro, Inc. (Iatan, MO)	B20	E-SAIBAM0-09A	BNSF 9267	C-ATMSAI0-11A
AT MINE	CMC Cordero Rojo	Georgia Power (Plant Scherer, GA)	B8	E-MHSCDM0-19A	NS 4722	C-CDMMHS0-21B
LOADING	ACC Antelope	Plum Point Energy Associates (Osceola, AR)	B24	E-OPPATM0-03B	BNSF 9079	C-ATMOPP0-05A
LOADING	ACC Antelope	Platte River Power Authority (Rawhide, CO)	B25	E-PRRATM0-20A	—	C-ATMPRR0-21A
LOADING	SCC Spring Creek	NTEC (Roberts Bank) (Export — CN)	—	E-RBCSCM0-90F	BNSF 8094	C-SCMRBC0-97F

Trains with Confirmed ETA

ETA	Mine	Customer	Train ID	Loco	Outbound ID
03:00	ACC Antelope	Tennessee Valley Authority (Shawnee, KY)	B22	E-CLSATM0-69A	BNSF 8791	C-ATMCLS0-75A
06:00	ACC Antelope	MidAmerican Energy Company (Council Bluffs, IA)	B23	E-OTLATM0-15A	BNSF 6416	C-ATMOTL0-16B
12:30	CMC Cordero Rojo	Luminant Energy Company (TX)	U12	F-CCLCD902/7	UP 8136	—

Trains Confirmed — ETA Later LATER

Railroad has confirmed these trains but has not yet provided an estimated arrival time. ETAs typically update as trains get closer to the mine.

Slot Time	Mine	Customer	Train ID	Loco	Outbound ID
No trains with “Later” ETA at this time — all confirmed trains have arrival estimates.

Departed — Loaded & Outbound

Departed	Mine	Customer	Train ID	Loco	Outbound ID
Apr 6 06:00	SCC Spring Creek	Minnesota Power (Ardoch, ND)	E-COBSCM0-25B	BNSF 9241	C-SCMCOB0-26B

Sources: BNSF 72-hour slot email (CONJCT, CORDERO, NERJCT) • UP slot assignments • Power Automate pipeline • CMS diversion cross-reference • Report timestamp: Apr 6, 2026 08:05 MT

Reference / spec library — alert counts, mine-average BTU/Ash/SO2 panels, and per-contract spec tables on this tab are a manually-maintained snapshot through early Apr 2026. Live BTU/ash/sulfur on shipments comes through Quality Compliance (Logistics → Quality Compliance) which is wired to CMS.

Critical Alerts

2

Exceeding contract limits · snapshot

High Alerts

14

Within warning threshold · snapshot

Medium Alerts

12

Within caution threshold · snapshot

Contracts Tracked

18

2026 contracts with quality specs

Mine Quality vs. Contract Limits — BTU (Btu/lb)

Mine Quality vs. Contract Limits — Ash (%)

Mine Quality vs. Contract Limits — SO₂ (lbs/mmBtu)

Mine Quality vs. Contract Limits — Moisture (%)

Active Quality Alerts — 2026 Contracts

Plum Point #2938 — SO₂ Exceeds LimitCritical

Cordero Rojo mine average SO₂ of 0.84 lbs/mmBtu exceeds contract limit of 0.52 lbs/mmBtu by 61.5%. Immediate review required — coordinate with mine ops & blending.

KOWEPO #3027 — SO₂ Exceeds LimitCritical

Spring Creek mine average SO₂ of 0.68 lbs/mmBtu exceeds KOWEPO contract limit of 0.35 lbs/mmBtu by 94.3%. This is an export contract — coordinate blending strategy for vessel loading.

Antelope BTU — 7 Contracts Below TargetWarning

Antelope mine average BTU of 8,800 is below target for 7 contracts (8,850–8,900 spec). Contracts affected: Western Fuels (#2911), WFA Holcomb (#2954), ADM (#2957), TVA (#2986), Colorado Springs (#2988), CSU (#2993), Alliant (#2995). Monitor blending to meet Btu adjustment thresholds.

Export Moisture — 6 Contracts Near LimitWarning

Spring Creek average moisture of 24.74% is within 11.6% of the 28.0% export limit across 6 export contracts (KOEN, JERA/Mitsubishi, KOWEPO, KOMIPO). Seasonal variation could push above threshold — track vessel sampling closely.

Export SO₂ — 5 Contracts in Caution ZoneInfo

Spring Creek SO₂ of 0.68 lbs/mmBtu is within 15% of the 0.80 limit on 5 export contracts. Currently compliant but with limited margin.

Mine Average BTU

8,800

Btu/lb • 2026 baseline

Ash

5.2%

Well within all limits

Sulfur

0.22%

Low sulfur advantage

Sodium

0.8%

52.9% margin to Ameren 1.7% limit

Antelope Mine — 2026 Contract Quality Specifications

Contract	Customer	Expiration	Tons	Parameter	Target/Limit	Mine Average	Margin	Status
2911	Western Fuels	Dec-26	120,000	BTU	8,900	8,800	-1.1%	Warning
2954	WFA (Holcomb)	Dec-26	200,000	BTU	8,875	8,800	-0.8%	Warning
2954	WFA (Holcomb)	Dec-26	200,000	Ash (%)	7.0% reject	5.2%	25.7%	✔ OK
2957	ADM	Dec-25	1,000,000	BTU	8,875	8,800	-0.8%	Warning
2962	Ameren	Dec-28	5,000,000	Sodium (%)	1.7% max	0.8%	52.9%	✔ OK
2986	TVA	Dec-28	5,500,000	BTU	8,850	8,800	-0.6%	Warning
2988	Colorado Springs	Dec-27	500,000	BTU	8,850	8,800	-0.6%	Warning
2993	CSU	Dec-27	700,000	BTU	8,900	8,800	-1.1%	Warning
2995	Alliant Energy	Dec-27	4,500,000	BTU	8,900	8,800	-1.1%	Warning
Source: Contract repository • Mine quality baselines • As of Mar 31, 2026. Penalty: WFA #2954 ash 7.0–7.5% = $0.15/ton (2 trains/yr exception).

Mine Average BTU

8,350

Btu/lb • 2026 baseline

Ash

5.8%

22.7% margin to Plum Point 7.5%

SO₂

0.84

EXCEEDS Plum Point 0.52 limit

Sulfur

0.35%

Moderate • within spec

Cordero Rojo — 2026 Contract Quality Specifications

Contract	Customer	Expiration	Tons	Parameter	Target/Limit	Mine Average	Margin	Status
2938	Plum Point	Dec-26	600,000	SO₂ (lbs/mmBtu)	0.52 max	0.84	-61.5%	❌ Exceeds
2938	Plum Point	Dec-26	600,000	Ash (%)	7.5% reject	5.8%	22.7%	✔ OK
2994	Alliant Energy	Dec-27	3,000,000	BTU	8,500	8,350	-1.8%	Warning
Source: Contract repository • Mine quality baselines • As of Mar 31, 2026. Critical: Plum Point SO₂ 0.52 limit cannot be met with standard CRD coal — blending required.

Mine Average BTU

9,400

Btu/lb • highest of 3 mines

Ash

4.2%

30% margin to 6.0% export limit

Moisture

24.74%

11.6% margin to 28% export limit

Mercury

0.05 ppm

58.3% margin to SRP 0.12 limit

Spring Creek — 2026 Contract Quality Specifications (Domestic)

Contract	Customer	Expiration	Tons	Parameter	Target/Limit	Mine Average	Margin	Status
2971	Minnesota Power	Dec-27	2,800,000	BTU	9,350	9,399	+0.5%	✔ OK
2996	Salt River Project	Dec-28	4,000,000	Mercury (ppm)	0.12 max	0.05	58.3%	✔ OK
Source: Contract repository • Mine quality baselines • As of Apr 2, 2026. Note: SRP mercury 0.12 ppm = suspension clause.

Spring Creek — 2026 Export Contract Quality Specifications

Contract	Customer	Tons	Parameter	Limit	Mine Average	Margin	Status	Penalty
2985	KOEN	550,000	BTU	9,350 tgt / 9,000 min	9,399	+0.5%	✔ OK	—
2985	KOEN	550,000	Ash (%)	6.0% max	4.54%	24.3%	✔ OK	15% FOB adj/1% over
2985	KOEN	550,000	Sulfur (%)	0.50% max	0.33%	34.0%	✔ OK	—
2985	KOEN	550,000	Moisture (%)	28.0% max	24.74%	11.6%	Warning	—
2985	KOEN	550,000	SO₂	0.80 max	0.68	15.0%	ⓘ Caution	—
3027	KOWEPO	200,000	SO₂	0.35 max	0.68	-94.3%	❌ Exceeds	—
3027	KOWEPO	200,000	Moisture (%)	28.0% max	24.74%	11.6%	Warning	15% FOB adj/1% over
3012	KOEN	300,000	Moisture (%)	28.0% max	24.74%	11.6%	Warning	—
3032	JERA/Mitsubishi	400,000	Moisture (%)	28.0% max	24.74%	11.6%	Warning	—
3019	KOMIPO	150,000	Moisture (%)	28.0% max	24.74%	11.6%	Warning	15% FOB adj/1% over
3054	KOMIPO	150,000	Moisture (%)	28.0% max	24.74%	11.6%	Warning	15% FOB adj/1% over
Source: SCM Tender Quality Tracking • Contract repository • As of Apr 2, 2026. All export contracts are Spring Creek Mine (SCM). Showing flagged params only — all other specs OK.

Complete Quality Alert Register — 2026 Contracts

ID	Severity	Contract	Customer	Mine	Parameter	Mine Average	Contract Limit	Margin	Action
QA-001	CRITICAL	2938	Plum Point	Cordero Rojo	SO₂	0.84	0.52	-61.5%	Blending required — CRD cannot meet spec alone
QA-002	CRITICAL	3027	KOWEPO	Spring Creek	SO₂	0.68	0.35	-94.3%	SCM cannot meet 0.35 spec — review contract
QA-003	MEDIUM	2911	Western Fuels	Antelope	BTU	9,011	8,900	+1.2%	Track trend — thin margin
QA-004	MEDIUM	2954	WFA (Holcomb)	Antelope	BTU	9,011	8,875	+1.5%	Track trend — Btu adj @ 8875 BB
QA-005	MEDIUM	2957	ADM	Antelope	BTU	9,011	8,875	+1.5%	Track trend — 8875 Btu product
QA-006	MEDIUM	2986	TVA	Antelope	BTU	9,011	8,850	+1.8%	Track trend — flag if quality shifts
QA-007	MEDIUM	2988	Colorado Springs	Antelope	BTU	9,011	8,850	+1.8%	Track trend — 8850 Btu product
QA-008	MEDIUM	2993	CSU	Antelope	BTU	9,011	8,900	+1.2%	Track trend — 8900 Btu product
QA-009	MEDIUM	2995	Alliant Energy	Antelope	BTU	9,011	8,900	+1.2%	Track trend — 8900 Btu product
QA-010	MEDIUM	2994	Alliant Energy	Cordero Rojo	BTU	8,554	8,500	+0.6%	Track trend — CRD thin margin
QA-011	MEDIUM	2985	KOEN	Spring Creek	Moisture	24.74%	28.0%	11.6%	Track vessel sampling — seasonal risk
QA-012	MEDIUM	3012	KOEN	Spring Creek	Moisture	24.74%	28.0%	11.6%	Track vessel sampling
QA-013	MEDIUM	3032	JERA/Mitsubishi	Spring Creek	Moisture	24.74%	28.0%	11.6%	Track vessel sampling
QA-014	MEDIUM	3027	KOWEPO	Spring Creek	Moisture	24.74%	28.0%	11.6%	Track vessel sampling
QA-015	MEDIUM	3019	KOMIPO	Spring Creek	Moisture	24.74%	28.0%	11.6%	Track vessel sampling
QA-016	MEDIUM	3054	KOMIPO	Spring Creek	Moisture	24.74%	28.0%	11.6%	Track vessel sampling
QA-017	MEDIUM	2985	KOEN	Spring Creek	SO₂	0.68	0.80	15.0%	Within caution zone — track
QA-018	MEDIUM	3012	KOEN	Spring Creek	SO₂	0.68	0.80	15.0%	Within caution zone
QA-019	MEDIUM	3032	JERA/Mitsubishi	Spring Creek	SO₂	0.68	0.80	15.0%	Within caution zone
QA-020	MEDIUM	3019	KOMIPO	Spring Creek	SO₂	0.68	0.80	15.0%	Within caution zone
QA-021	MEDIUM	3054	KOMIPO	Spring Creek	SO₂	0.68	0.80	15.0%	Within caution zone
Source: Quality specs data layer • quality_alerts_2026-04-02.csv • Generated Apr 2, 2026. Margin = distance from limit (negative = exceeds). Baselines updated from 2026 YTD CMS + Pace weighted avg.

BTU by Mine — Monthly Trend (2026 YTD)CMS Apr 7

Ash % by Mine — Monthly TrendCMS Apr 7

Moisture % by Mine — Monthly TrendCMS Apr 7

SO2 (lbs/mmBtu) by Mine — Monthly TrendCMS Apr 7

Quality Summary by Mine — YTD Weighted Averages

Mine	BTU	Ash %	Moisture %	Sodium %	SO2 (lbs/mmBtu)	Assessment
ACC Antelope	9,004	4.74	25.78	1.36	0.489	Within spec
CMC Cordero Rojo	8,556	5.45	28.83	1.37	0.654	Within spec
SCC Spring Creek	9,389	4.52	24.81	7.17	0.703	Sodium elevated
NTEC Blended	8,965	4.89	26.42	2.66	0.580	—

Spring Creek SodiumSCC sodium averaging 7.17% YTD, well above ACC/CMC levels (~1.4%). Monitor against customer quality specs. Some contracts (e.g., Alabama Power #2941) have ash restrictions of 7% with $0.15/ton penalty.

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Monthly Budget by Mine — 2026 Plan (ktons)2026 plan

YTD Actual vs. Annualized Pace vs. Budget2026 plan · CMS live

Mine Performance — Pace Detail

Mine	Jan	Feb	Mar	YTD Total	Annual Pace	Budget	Variance	Pace
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Monthly actuals + YTD come from live CMS data. Annual Pace = YTD / days elapsed × 365. Budgets per 2026 executive plan (Spring Creek = 4.1M domestic + 5.4M export = 9.5M total).

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Rolling 4-Week Comparison — Weekly Trains & TonnageCMS

This Week

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Last Week

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4-Week Avg

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Rolling average

vs. 4-Wk Avg

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This week vs average

Sales Book

Sales Book — coming soon.

Market Share

Market Share — coming soon.

Live Grid & Demand PulseReal-time fuel mix from the EIA Hourly Grid Monitor (US48 + 11 regions) and the SPP and ERCOT ISO feeds. Forward signals from NOAA 6–10 / 8–14 day outlooks, plant-level weather, drought, and active severe weather alerts. Refreshed every 15 minutes.

US48 Coal Share

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SPP Coal Now

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Active Severe/Extreme Alerts

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NWS, mine + buyer states

U.S. Generation Mix (Now)

Coal Share by Region (Now)

Daily Coal vs. Natural Gas Generation — MISO / SPP / PJM

Daily MWh by ISO & fuel. When coal rises relative to gas, plants are dispatching coal — a real-time sign of coal demand health.

Live MarketsCoal-sector equities (Stooq), forward futures curves (CME), and macro indicators (FRED). Equities and macro refresh on each refresh_live_data run; CME quotes intermittently rate-limit.

PRB Front Month

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CME TRA

Henry Hub Front

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CME NG

BTU (Peabody)

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ARCH (Arch)

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Coal Producer Equities (60-day)

Ticker	Company	Last	Day Δ%	Trend (60d)

PRB Futures Curve (CME TRA)

CME endpoint can rate-limit; values populate when the connector returns data.

International Coal Benchmarks

Index	Front Month	Last	Settle	Δ

API-2 (Rotterdam), API-4 (Richards Bay), Newcastle — sets the international thermal coal context for export decisions.

Macro Indicators (FRED)

Series	Latest	Date	Δ%

Intel & FilingsRecent SEC filings from coal producers and major utility customers (10-K / 10-Q / 8-K), EPA & DOE coal-relevant rulemakings, BLM Federal Register coal notices, and a sentiment-scored news pulse from GDELT + NewsAPI.

Recent SEC Filings (Peers + Buyers)

Filed	Ticker	Company	Form

EPA Coal Rulemaking Dockets Regulations.gov

Posted	Type	Title	Comment Due

BLM Coal Notices (Federal Register, last 18 mo)

Published	Type	Title

News Pulse (GDELT + NewsAPI, sentiment-tinted)

Items tinted green for positive tone, red for negative (GDELT). NewsAPI items shown without tone scoring.

A.T.L.A.S. Dashboard

Welcome to ATLAS

Home Dashboard

My Dashboard

Coal Quality Compliance

Slot Plan Execution

Missed Opportunities

Railroad Nominations

End-of-Month Forecast Report

Customer Concentration Risk

Contract vs Actual Variance

Contract Intelligence

Weather & Demand Correlation

Vessel Schedule

Rail Lineup & Cycle Time

Train Plan & In Transit

Demurrage

Daily Pulse

Week in Review

Monthly Executive Summary

Yesterday’s Activity

Month-to-Date

Coal Market News

ATLAS Dashboard

👤 Your Account

☀ Appearance

What you can do at this role

Preview as another role

Source Freshness —

🕑 Refresh Schedule

Database Connections

ATLAS PostgreSQL default

CMS SQL Server not configured

Add New Connection

👥 User Management

Add New User

Role Permissions

Data Connectors

Add New Connector

📤 Upload CSV Data

🔑 API Keys

Add API Key

🔔 Notifications

🔃 Historical Data Backfill

System Settings

📦 Docker Status

📄 About ATLAS Dashboard

📜 Audit Trail

Budget / Forecast

Sales Book

Market Share