Operational - Quarterly Summary

 

Q2 2017 Q1 2017 Q4 
2016
Q3 2016 Q2 2016

Q1 2016

Q4 2015

Q3 2015

Operating Highlights                

Gas

               
Total inlet gas processed (Mmcf/d) (1) 1,300 1,404 1,337 1,275 1,083 1,222 1,298 1,293
Extraction volumes (Bbls/d) (1)(2) 58,885 71,958 69,687 65,509 58,065 64,408 65,465 30,241
Frac spread - realized ($/Bbl) (1)(3) 9.06 10.56 6.11 6.29 10.00 8.22 15.55 34.58
Frac spread - average spot price ($/Bbl) (1)(4) 10.98 17.26 8.4 6.29 10.62 8.22 5.06 11.11

Power

               
Renewable power sold (GWh) 499 148 196 670 544 142 310 487
Conventionable power sold (GWh) 409 385 374 587 293 698 1,264 1,210
Renewable capacity factor (%) 50.7 9.5 18.8 70.2 56.8 10.05 30.2 57.5
Contracted conventional availability factor (%) 99.9 96.0 99.8 99.3 92.4 97.6 99.1 99.5

Utilities

               

Canadian utilities

               
Natural gas deliveries - end use (PJ) (5) 4.8 13.5 10.8 3.2 4.8 12.3 10.2 3.3
Natural gas deliveries - transportation (PJ) (5) 1.5 1.9 1.5 1.1 1.5 1.8 1.9 1.6

US utilities

               
Natural gas deliveries - end use (Bcf) (5) 10.3 30.2 22.8 5.4 10.3 28.2 20.2 5.9
Natural gas deliveries - transportation (Bcf) (5) 11.5 15.4 14.2 11.0 11.8 14.2 13.5 10.5

Service sites (6)

575,084 576,829 574,875 568,628 568,606 570,681 568,751 562,301
Degree day variance from normal - AUI (7) (7.4) (2.2) (0.6) (8.4) (28.0) (18.5) (10.0) 3.9
Degree day variance from normal - Heritage Gas (7) (4.3) (1.9) (1) (7.4) 3.6 (6.9) (8.0) (42.0)
Degree day variance from normal - SEMCO Gas (8) (8.4) (11.8) (6.1) (57.6) 11.8 (8.5) (20.4) (28.4)
Degree day variance from normal - ENSTAR (8) (5.4) 9.6 (1.4) (36.1) (26.4) (21.0) (6.1) (9.6)

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, 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.