Operational - Quarterly Summary
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Q1 2019 |
Q4 2018 |
Q3 2018 |
Q2 2018 |
Q1 2018 |
Q4 2017 |
Q3 2017 |
Q2 2017 |
Utilities |
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| Natural gas deliveries - end use (Bcf) (1) | 75.4 | 58.5 | 10.9 | 12.0 | 31.0 | 24.3 | 5.9 | 10.3 |
| Natural gas deliveries - transportation (Bcf) (1) | 47.6 | 52 | 25.7 | 10.9 | 13.4 | 14.2 | 10.9 | 11.5 |
| Service sites (2) | 1,647,461 | 1,642,523 | 1,759,154 | 580,526 | 582,871 | 581,518 | 575,602 | 575,084 |
| Degree day variance from normal – SEMCO Gas (3) | 5.7 | 7.5 | (17.8) | 14.8 | 3.0 | 4.8 | 5.7 | (8.4) |
| Degree day variance from normal – ENSTAR (3) | (9.4) | (19.6) | (31.2) | (6.1) | (1.7) | (8.3) | (16.6) | (5.4) |
| Degree day variance from normal – Washington Gas (%) (3)(4) | (1.1) | 0.4 | (4.1) | – | – | – | – | – |
Midstream |
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| Total inlet gas processed (Mmcf/d) (5) | 1,481 | 1,413 | 1,333 | 1,227 | 1,553 | 1,424 | 1,322 | 1,300 |
| Extraction volumes (Bbls/d) (5)(6) | 62,332 | 64,522 | 60,945 | 49,728 | 74,786 | 68,306 | 64,026 | 58,885 |
| Frac spread – realized ($/Bbl) (5)(7) | 16.84 | 15.84 | 15.60 | 14.98 | 19.01 | 18.02 | 14.96 | 9.06 |
| Frac spread – average spot price ($/Bbl) (5)(8) | 11.79 | 21.00 | 25.87 | 22.19 | 22.25 | 30.66 | 21.28 | 10.98 |
| WGL retail energy marketing – gas sales volumes (Mmcf) | 27,411 | 20,750 | 8,155 | – | – | – | – | – |
Power |
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| Renewable power sold (GWh) | 141 | 223 | 690 | 504 | 126 | 301 | 681 | 499 |
| Conventionable power sold (GWh) | 263 | 985 | 1,255 | 642 | 842 | 1,059 | 922 | 409 |
| Renewable capacity factor (%) | 12.2 | 14.6 | 44.6 | 51.7 | 8.1 | 27.5 | 70.3 | 50.7 |
| Contracted conventional availability factor (%) (9) | 43.2 | 97.4 | 98.5 | 97.7 | 94.5 | 96.3 | 99.6 | 99.9 |
| WGL retail energy marketing – electricity sales volumes (GWh) | 3,080 | 2,911 | 3,000 | – | – | – | – | – |
Notes:
(1) Petajoule (PJ) is one million gigajoules (GJ). Bcf is one billion cubic feet.
(2) Service sites reflect all of the service sites of AUI, PNG, Heritage Gas, and U.S. Utilities, including transportation and non-regulated business lines.
(3) A degree day for U.S. Utilities is a measure of coldness, determined daily as the number of degrees the average temperature during the day in question is below 65 degrees Fahrenheit. Degree days for a particular period are determined by adding the degree days incurred during each day of the period. Normal degree days for a particular period are the average of degree days during the prior 15 years for SEMCO Energy Gas Company, during the prior 10 years for ENSTAR, and during the prior 30 years for Washington Gas."
(4) In certain of Washington Gas’ jurisdictions (Virginia and Maryland) there are billing mechanisms in place which are designed to eliminate the effects of variance in customer usage caused by weather and other factors such as conservation. In the District of Columbia, there is no weather normalization billing mechanism nor does it hedge to offset the effects of weather. As a result, colder or warmer weather will result in variances to financial results.
(5) Average for the period.
(6) Includes Harmattan NGL processed on behalf of customers.
(7) Realized frac spread or NGL margin, expressed in dollars per barrel of NGL, is derived from sales recorded by the segment during the period for frac
exposed volumes plus the settlement value of frac hedges settled in the period less extraction premiums, divided by the total frac exposed volumes
produced during the period.
(8) Average spot frac spread or NGL margin, expressed in dollars per barrel of NGL, is indicative of the average sales price that AltaGas receives for
propane, butane and condensate less extraction premiums, before accounting for hedges, divided by the respective frac exposed volumes for the period.
(9) Calculated as the availability factor contracted under long-term tolling arrangements adjusted for occasions where partial or excess capacity payments have been added or deducted.