Operational - Quarterly Summary

 

Q3
2018
Q2 2018 Q1
2018
Q4
2017
Q3
2017
Q2
2017
Q1
2017
Q4
2016
Operating Highlights                

Gas

               
Total inlet gas processed (Mmcf/d) (1) 1,333 1,227 1,553 1,424 1,322 1,300 1,404 1,337
Extraction volumes (Bbls/d) (1)(2) 60,945 49,728 74,786 68,306 64,026 58,885 71,958 69,687
Frac spread - realized ($/Bbl) (1)(3) 15.60 14.98 19.01 18.02 14.96 9.06 10.56 6.11
Frac spread - average spot price ($/Bbl) (1)(4) 25.87 22.19 22.25 30.66 21.28 10.98 17.26 8.40
WGL retail energy marketing - gas sales volumes (Mmcf)  8,155

Power

               
Renewable power sold (GWh) 690 504 126 301 681 499 148 196
Conventionable power sold (GWh) 1,255 642 842 1059 992 409 385 374
Renewable capacity factor (%) 44.6 51.7 8.1 27.5 70.3 50.7 9.5 18.8
Contracted conventional availability factor (%) (5) 98.5 97.7 94.5 96.3 99.6 99.9 96.0 99.8
WGL retail energy marketing - electricity sales volumes (GWh) 3,000

Utilities

               

Canadian utilities

               
Natural gas deliveries - end use (PJ) (6) 3.5 5.6 14.1 11.2 3.7 4.8 13.5 10.8
Natural gas deliveries - transportation (PJ) (6) 1.1 1.4 1.8 1.6 1.3 1.5 1.9 1.5

US utilities

               
Natural gas deliveries - end use (Bcf) (6) 10.9 12.0 31.0 24.3 5.9 10.3 30.2 22.8
Natural gas deliveries - transportation (Bcf) (6) 25.7 10.9 13.4 14.2 10.9 11.5 15.4 14.2

Service sites (7)

1,759,154 580,526 582,871 581,518 575,602 575,084 576,829 574,875
Degree day variance from normal - AUI (8) 80.0 3.9 10.2 4.0 (16.9) (7.4) (2.2) (0.6)
Degree day variance from normal - Heritage Gas (8) (16.5) 6.7 (8.1) (4.6) (20.4) (4.3) (1.9) (1.0)
Degree day variance from normal - SEMCO Gas (9) (17.8) 14.8 3.0 4.8 5.7 (8.4) (11.8) (6.1)
Degree day variance from normal - ENSTAR (9) (31.2) (6.1) (1.7) (8.3) (16.6) (5.4) 9.6 (1.4)
Degree day variance from normal - Washington Gas (%) (9)(10) (4.1)

Notes:

(1) Average for the period.
(2) Includes Harmattan NGL processed on behalf of customers.
(3) 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.
(4) 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.
(5) 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.
(6) Petajoule (PJ) is one million gigajoules (GJ). Bcf is one billion cubic feet.
(7) Service sites reflect all of the service sites of AUI, PNG, Heritage Gas, and U.S. Utilities, including transportation and non-regulated business lines.
(8) A degree day for AUI and Heritage Gas is the cumulative extent to which the daily mean temperature falls below 15 degrees Celsius at AUI and 18 degrees Celsius at Heritage Gas. Normal degree days are based on a 20-year rolling average. Positive variances from normal lead to increased delivery volumes from normal expectations. Degree day variances do not materially affect the results of PNG as the British Columbia Utilities Commission (BCUC) has approved a rate stabilization mechanism for its residential and small commercial customers.
(9) 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 and during the prior 10 years for ENSTAR.
(10) 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.