Hydro Conditions and Purchase Power Monthly Outlook January 31, 2013

Western Summary

The most probable forecast of net generation for FY 2013 is 25,909 Gigawatthours (GWh) or 95 percent of average. October through December generation was 83 percent of average. The lower level forecast of generation for FY 2013 is 24,906 GWh or 92 percent of average. The amount of power purchased for FY 2013 is expected to range between 2,806 and 3,125 GWh. The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $45/MWh. This price compares to $47/MWh last year. Purchase power expenses for FY 2013 are forecast to range between $127 and $137 million – compared to $100 million in FY 2012. October through December purchases totaled $53 million – compared to $25 million for the same period last year.

Cumulative of Actual Purchase Power Expenses - FY 13 $150

Most $125 Probable/Actual Dry

$100

$75

$50

Millions of Dollars of Millions $25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month Upper Great Plains Region

Storage: Streamflows into Canyon Ferry improved to 91 percent of average during December. The January 1 water supply forecast indicates the runoff into Canyon Ferry during January will equal 186.0 acre-feet (85% of average). With storage in Canyon Ferry at about 95 percent of average and the anticipated inflows during the April through July period remaining slightly below average, releases out of Canyon Ferry to the Missouri River below Holter Dam will be maintained near 4,300 cfs. Streamflows into Bighorn Lake during November continued to remain well below average at only 74% of average. Based on the January 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the December runoff into Bighorn Lake is expected to equal 812,000 acre-feet (69% of average.

As of January 21, 2013, the storage level at Canyon Ferry was 1,545,938 acre feet and the active conservation pool is 81.7% full. Storage at Yellowtail is 895,468 acre feet and the active conservation pool is 87.7% full.

COE Runoff: Total runoff for the year is estimated to be only 79% of normal at 19.7 MAF, normal being 24.8 MAF. This may result in lower generation in future months, especially if drought conditions remain.

Snow pack: As of January 1, 2013, the mountain snowpack in the reach above Fort Peck is 101% of the average snowpack for this date. Mountain snowpack in the reach between Fort Peck and Garrison is 91% of the average snowpack for this date.

FY Generation: The six main stem power plants generated 568 million kilowatt hours of electricity in December. Total energy production for 2012 was earlier forecasted to reach 14.1 billion kWh, but has been reduced to around 10.3 billion KWh. The long-term average is approximately 10 billion kWh.

Purchased Power: With colder temperatures at this time of year, prices are at holding steady at lower 30s for on peak power and lower 20s for off peak power. Jan – Mar prices look to be in the high thirties for on peak power and mid to upper twenties for off peak power.

Rocky Mountain Region

The Loveland Area Projects (LAP) reside in both the Upper Missouri and Upper Colorado basins. Hydrologic conditions can vary from one river basin and watershed to another. The three LAP watersheds are the Bighorn River Basin in Wyoming, the North Platte River Basin in Colorado and Wyoming, and the headwaters of the Colorado River Basin in Colorado.

Drought conditions persist in the entire LAP area and range from moderate to exceptional. The reservoir inflow has been well below normal in all three LAP basins so far this year. The accumulated snowpack was below average at the beginning of the month ranging from well below average in the Colorado River headwaters to near average in the Bighorn Basin. The reservoir storage at the end of December was well below average and significantly less than it was at the end of last December. The latest National Weather Service forecast for the February through April period indicates temperatures and precipitation are just as likely to be above average as below average in Wyoming. In Colorado the temperatures are more likely to be above average and the precipitation more likely below average. Reclamation is forecasting below average spring reservoir inflows based on snowpack and other factors.

LAP Water Conditions At-A-Glance

Reservoir Storage Snowpack Most Probable Reservoir Inflow 1,000 acre-feet inches snow water equivalent 1,000 acre-feet (April - July) end of % of end of % of January % of December average average December average average forecast average average

CBT 473.7 661.1 72% 60.2 90.3 67% 480.9 618.3 78%

North Platte 1,149.0 1,394.5 82% 100.5 125.6 80% 490.0 714.0 69%

Bighorn 1,861.4 1,875.7 99% 128.8 131.5 98% 1,179.9 1,435.3 82%

TOTAL 3,484.1 3,931.3 89% 289.5 347.4 83% 2,150.8 2,767.6 78%

Net At Plant Generation Projections (GWh)

Most Probable Case Reasonable Minimum Case Reasonable Maximum Case median inflow lower decile inflow upper decile inflow January % of January % of January % of projection average average projection average average projection average average

Winter 12-13 486.7 724.0 67% 484.4 724.0 67% 498.8 724.0 69%

Summer 13 1,219.1 1,214.7 100% 1,002.1 1,214.7 82% 1,415.1 1,214.7 116%

TOTAL 2013 1,705.8 1,938.7 88% 1,486.5 1,938.7 77% 1,913.9 1,938.7 99%

LAP generation will be well below average this winter. An extended CBT outage restricted all CBT generation other than at Green Mountain in November and December. There are minimum releases from Seminoe and Pathfinder reservoirs this winter due to lower carryover storage in those reservoirs. The winter release from Bighorn Lake is higher than in other recent drought years but still below average. LAP generation is expected to be above average in the late spring and early summer, below average mid-summer, and near average later in the season. Reclamation is planning to limit Adams Tunnel imports to 250 cfs in July and August as a means to improve the water clarity of Grand Lake by reducing the introduction of suspended sediment and organic matter from Shadow Mountain Reservoir.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 16,970,000 acre feet, which is about 55 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (December, 2012) were about 58 percent of average. Lake Powell elevation currently is about 3,608 feet, 92 feet from maximum reservoir level. The elevation is projected to continue to drop over the winter months before bottoming out at about 3,599 feet next April. The January, 2013 inflow forecast for April through July, 2013 at Lake Powell is 61 percent of average.

SLCA/IP net generation for Fiscal Year 2013 is 4,209 GWh as compared to 5,607 GWh based on the long-term historical average generation.

Total purchase power expenses for firming during the fiscal year 2013 are about $34.6 million as compared to about $14.5 million based on long–term median historical releases. Purchase power availability in the region is abundant and prices are reasonable.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 15.758 MAF (15.422 MAF Nov-2012), 20.918 MAF (73-Year Historical Avg).

The Lake Mead end of December 2012 elevation was 1,120.36 ft. (3.12 ft. higher than end of Nov 2012 elevation ), or about 99.28 ft. below full storage elevation of 1,219.64 ft. and 70.36 ft. above the minimum generation elevation for Hoover of 1,050 ft.

Lake Mead’s elevation is projected to peak at 1122.39 ft in January of WY 2013 (11.79 ft. below the WY 2012 peak elevation of 1134.18 ft.), and drop to a minimum elevation of 1104.36 ft. in September of WY 2013, a maximum fluctuation in lake elevation of 18.03 ft.

The Lake Powell operational tier for WY 2013 is currently the Upper Elevation Balancing Tier. Total releases from Lake Powell are projected to be average at 8.23 MAF for WY 2013 (actual of 9.466 MAF for WY 2012). The projected 2013 April – July unregulated inflow into Lake Powell is 4.4 MAF or 61% of average (actual of 2.06 MAF or 29% of average for 2012).

Basin Snow Pack and Precipitation: DSW hydrology is mostly dependent on the Colorado River Basin snow pack and precipitation above Lake Powell. The WY 2013 precipitation is currently 73% of average and the snowpack is 77% of average.

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for December 2012 was 50 KAF. The projected side inflow into Lake Mead for WY2013 is 821 KAF which represents a 12% increase over last year’s actual of 732 KAF, and represents 63% of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2013 Generation: 5249 GWh compared to 5646 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2013 is 93% of the average historical generation.

Wholesale Power Market Conditions: The December market prices in the Desert Southwest averaged about $30/MWh firm on-peak, $25/MWh firm off-peak compared to $29/MWh firm on- peak, $26/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 7. 536 million-acre-feet, compared to 7.414 MAF last year. Accumulated inflow for the water year-to-date is 115 percent of the 15-year average for Trinity, 108 percent for Shasta, 145 percent for Folsom and 94 percent for New Melones. None of the reservoirs is in flood control operations at this time.

Hydro Conditions and Purchase Power Monthly Outlook February 28, 2013

Western Summary

 The most probable forecast of net generation for FY 2013 is 25,478 Gigawatthours (GWh) or 94 percent of average. October through January generation was 83 percent of average.  The lower level forecast of generation for FY 2013 is 24,472 GWh or 90 percent of average.  The amount of power purchased for FY 2013 is expected to range between 3,531 and 3,948 GWh.  The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $45/MWh. This price compares to $47/MWh last year.  Purchase power expenses for FY 2013 are forecast to range between $161 and $174 million – compared to $100 million in FY 2012.  October through January purchases totaled $74 million – compared to $33 million for the same period last year.

Cumulative of Actual Purchase Power Expenses - FY 13 $200

$175 Most Probable/Actual Dry

$150

$125

$100

$75

$50 Millions of Dollars of Millions $25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month Upper Great Plains Region

Storage: Streamflows into Canyon Ferry was 92 percent of average during January. Storage in Canyon Ferry is at 98 percent of average and the anticipated inflows during the April through July period is 88 percent of average. Therefore, in preparation for the anticipated spring runoff, releases out of Canyon Ferry to the Missouri River below Holter Dam will be maintained near 4,500 cfs. Streamflows into Bighorn Lake during January continued to remain well below average at only 71% of average. Based on the January 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the April through July runoff into Bighorn Lake is expected to equal 788,000 acre- feet (67% of average).

As of February 18, 2013, the storage level at Canyon Ferry was 1,523,975 acre feet and the active conservation pool is 80.6% full. Storage at Yellowtail is 885,660 acre feet and the active conservation pool is 86.8% full.

COE: Total runoff for the year is estimated to be only 80% of normal at 19.9 MAF, normal being 24.8 MAF. This may result in lower generation in future months, especially if drought conditions remain.

Snow Pack: As of February 1, 2013, the mountain snowpack in the reach above Fort Peck is 92% of the average snowpack for this date. Mountain snowpack in the reach between Fort Peck and Garrison is 84% of the average snowpack for this date.

FY Generation: The six main stem power plants generated 634 million kilowatt hours of electricity in January. Total energy production for 2013 was earlier forecasted to reach 8.0 billion kWh, but has been reduced to around 7.8 billion KWh. The long-term average is approximately 10 billion kWh.

Purchased Power: Generally prices are staying within the mid twenties for off peak power and mid thirties for on peak power.

Rocky Mountain Region

Drought conditions persist in the entire LAP area and range from moderate to exceptional with conditions worsening farther east. The reservoir inflow has been well below normal in all three LAP basins so far this year. The accumulated snowpack at the beginning of the month was below average in the Bighorn Basin and well below average in the North Platte Basin and the Colorado River headwaters. The reservoir storage at the end of January was near average in the Bighorn Basin and below average in the North Platte Basin and the Colorado-Big Thompson Project (CBT). The reservoir storage was less than it was at the end of last January in all three basins. The latest National Weather Service forecast for the March through May period indicates temperatures are just as likely to be above average as below average in Wyoming while precipitation is more likely to be below average. In Colorado the temperatures are more likely to be above average and precipitation is more likely to be below average. Reclamation is forecasting well below average spring reservoir inflows based on snowpack and other factors.

LAP Water Conditions At-A-Glance

Reservoir Storage Snowpack Most Probable Reservoir Inflow 1,000 acre-feet inches snow water equivalent 1,000 acre-feet (April - July) end of % of end of % of February % of January average average January average average forecast average average

CBT 466.5 649.9 72% 158.8 246.2 65% 423.0 590.0 72%

North Platte 1,174.8 1,432.5 82% 167.0 231.7 72% 260.0 750.0 35%

Bighorn 1,840.5 1,800.3 102% 215.8 244.1 88% 1,112.4 1,435.3 78%

TOTAL 3,481.8 3,882.7 90% 541.6 722.0 75% 1,795.4 2,775.3 65%

Net At Plant Generation Projections (GWh)

Most Probable Case Reasonable Minimum Case Reasonable Maximum Case median inflow lower decile inflow upper decile inflow February % of February % of February % of projection average average projection average average projection average average

Winter 12-13 487.8 724.0 67% 484.3 724.0 67% 500.6 724.0 69%

Summer 13 981.0 1,214.7 81% 716.9 1,214.7 59% 1,357.5 1,214.7 112%

TOTAL 2013 1,468.8 1,938.7 76% 1,201.2 1,938.7 62% 1,858.1 1,938.7 96%

LAP generation will be well below average for the entire winter. An extended CBT outage restricted all CBT generation other than at Green Mountain in November and December. There are minimum releases from Seminoe and Pathfinder reservoirs due to lower carryover storage in those reservoirs and low spring inflow forecasts. The winter release from Bighorn Lake is higher than in other recent drought years but still below average. LAP generation is now expected to be below average through the end of the year. Reclamation is planning to limit Adams Tunnel imports to a constant 250 cfs in July and August as a means to improve the water clarity of Grand Lake by minimizing the mixing of introduced suspended sediment and organic matter from Shadow Mountain Reservoir with the clearer Grand Lake waters.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 16,491,000 acre feet, which is about 53 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (January, 2013) were about 52 percent of average. Lake Powell elevation currently is about 3,603 feet, 97 feet from maximum reservoir level. The elevation is projected to continue to drop over the winter months before bottoming out at about 3,598 feet next April. The February, 2013 inflow forecast for April through July, 2013 at Lake Powell is 54 percent of average.

SLCA/IP net generation for Fiscal Year 2013 is 4,227 GWh as compared to 5,607 GWh based on the long-term historical average generation.

Total purchase power expenses for firming during the fiscal year 2013 are about $36 million as compared to about $14.5 million based on long–term median historical releases. Purchase power availability in the region is abundant and prices are reasonable for this time of year.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 16.058 MAF (15.758 MAF Dec-2012), 21.059 MAF (73-Year Historical Avg).

The Lake Mead end of January 2013 elevation was 1,122.32 ft. (1.96 ft. higher than end of Dec 2012 elevation ), or about 97.32 ft. below full storage elevation of 1,219.64 ft. and 72.32 ft. above the minimum generation elevation for Hoover of 1,050 ft.

Lake Mead’s elevation is projected to peak at 1122.52 ft in February of WY 2013 (11.66 ft. below the WY 2012 peak elevation of 1134.18 ft.), and drop to a minimum elevation of 1104.14 ft. in September of WY 2013, a maximum fluctuation in lake elevation of 18.38 ft.

The Lake Powell operational tier for WY 2013 is currently the Upper Elevation Balancing Tier. Total releases from Lake Powell are projected to be average at 8.23 MAF for WY 2013 (actual of 9.466 MAF for WY 2012). The projected 2013 April – July unregulated inflow into Lake Powell is 3.85 MAF or 54% of average (actual of 2.06 MAF or 29% of average for 2012).

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for January 2013 was 56 KAF. The projected side inflow into Lake Mead for WY2013 is 799 KAF which represents a 9% increase over last year’s actual of 732 KAF, and represents 61% of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2013 Generation: 5275 GWh compared to 5644 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2013 is 93% of the average historical generation.

Wholesale Power Market Conditions: The January market prices in the Desert Southwest averaged about $32/MWh firm on-peak, $25/MWh firm off-peak compared to $30/MWh firm on-peak, $25/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 7. 706 million-acre-feet, compared to 7.483 MAF last year. Accumulated inflow for the water year-to-date is 106 percent of the 15-year average for Trinity, 99 percent for Shasta, 125 percent for Folsom and 91 percent for New Melones. None of the reservoirs is in flood control operations at this time.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak April 1st. Therefore, snow water equivalents are reported as a percentage of this average. As of February 14th, the North is at 60 percent, the Central is at 57 percent and the South is at 51 percent of this average. The Sacramento River Index forecast of water supply based upon February 1st conditions is “below normal” for the 90 percent exceedence case and “above normal” for the 50 percent case, reflecting the poor January, which has the highest average of the winter months.

Hydro Conditions and Purchase Power Monthly Outlook March 2013

Western Summary

The most probable forecast of net generation for FY 2013 is 23,887 Gigawatthours (GWh) or 88 percent of average. October through February generation was 82 percent of average. The lower level forecast of generation for FY 2013 is 22,605 GWh or 83 percent of average. The amount of power purchased for FY 2013 is expected to range between 3,610 and 4,056 GWh. The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $42/MWh. This price compares to $52/MWh last year. Purchase power expenses for FY 2013 are forecast to range between $153 and $168 million – compared to $100 million in FY 2012. October through February purchases totaled $92 million – compared to $44 million for the same period last year.

Cumulative of Actual Purchase Power Expenses - FY 13 $200

$175 Most Probable/Actual Dry

$150

$125

$100

$75

$50 Millions of Dollars of Millions $25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month Upper Great Plains Region

Storage: Based upon a 30 year average, streamflows into Canyon Ferry was 100 percent of average during February. Storage in Canyon Ferry is at 103 percent of average and the anticipated inflows during the April through July period is 89 percent of average. Therefore, based upon the current water supply forecast releases out of Canyon Ferry to the Missouri River below Holter Dam will be maintained near 4,700 cfs. Streamflows into Bighorn Lake during February continued to remain below average at only 78% of average. Based on the March 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the April through July runoff into Bighorn Lake is expected to equal 688,000 acre-feet (63% of average).

As of March 18, 2013, the storage level at Canyon Ferry was 1,471,193 acre feet and the active conservation pool is 77.8% full. Storage at Yellowtail is 885,746 acre feet and the active conservation pool is 86.8% full.

COE: Total runoff for the year is estimated to be only 80% of normal at 19.9 MAF, normal being 24.8 MAF. This may result in lower generation in future months, especially if drought conditions remain. The COE continues to operate in drought mode.

Snow pack: The March 1 forecasted runoff for calendar year 2013 is 20.0 MAF. This runoff would be 81% of normal runoff. As of March 1, 2013, the mountain snowpack in the reach above Fort Peck is 93% of the average snowpack for this date. Mountain snowpack in the reach between Fort Peck and Garrison is 86% of the average snowpack for this date.

FY Generation: The six main stem power plants generated 601 million kilowatt hours of electricity in January. Total energy production for 2013 was earlier forecasted to reach 8.0 billion kWh, but has been reduced to around 7.8 billion KWh. The long-term average is approximately 10 billion kWh.

Purchased Power: Generally prices are staying within the mid twenties for off peak power and mid thirties for on peak power. Rocky Mountain Region

Drought conditions persist in the entire LAP area and range from moderate to exceptional with conditions worsening farther east. The reservoir inflow has been well below normal in all three LAP basins so far this year. The accumulated snowpack at the beginning of the month was below average in the Bighorn Basin and well below average in the North Platte Basin and the Colorado River headwaters. The reservoir storage at the end of February was near average in the Bighorn Basin and below average in the North Platte Basin and the Colorado-Big Thompson Project (CBT). The reservoir storage was less than it was at the end of last February in all three basins. The latest National Weather Service forecast for the April through June period indicates temperatures are more likely to be above average in Wyoming and Colorado. Precipitation is just as likely to be above as below average in the LAP area. Reclamation is forecasting well below average spring reservoir inflows based on snowpack and other factors with the inflow to Seminoe Reservoir forecast to be especially low.

LAP Water Conditions At-A-Glance

Reservoir Storage Snowpack Most Probable Reservoir Inflow 1,000 acre-feet inches snow water equivalent 1,000 acre-feet (April - July) end of % of end of % of March % of February average average February average average forecast average average

CBT 461.9 607.3 76% 213.5 319.1 67% 418.0 590.0 71%

North Platte 1,205.5 1,470.2 82% 237.6 305.7 78% 260.0 750.0 35%

Bighorn 1,830.6 1,777.3 103% 266.9 301.3 89% 1,010.0 1,435.3 70%

TOTAL 3,498.0 3,854.8 91% 718.0 926.1 78% 1,688.0 2,775.3 61%

Net At Plant Generation Projections (GWh)

Most Probable Case Reasonable Minimum Case Reasonable Maximum Case median inflow lower decile inflow upper decile inflow March % of March % of March % of projection average average projection average average projection average average

Winter 12-13 504.1 724.0 70% 504.0 724.0 70% 513.1 724.0 71%

Summer 13 973.0 1,214.7 80% 722.6 1,214.7 59% 1,374.6 1,214.7 113%

TOTAL 2013 1,477.1 1,938.7 76% 1,226.6 1,938.7 63% 1,887.7 1,938.7 97%

LAP generation will end up well below average for the entire winter. LAP generation is now expected to be below average through the end of the year. Based on reservoir inflow forecasts and an expected low water quota declaration, Reclamation is now considering a four to six week curtailment of Adams Tunnel imports and associated CBT generation this summer as a means to improve the water clarity of Grand Lake by minimizing the introduction of suspended sediment and organic matter from Shadow Mountain Reservoir to the clearer Grand Lake waters.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 16,185,000 acre feet, which is about 52 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (February, 2013) were about 67 percent of average. Lake Powell elevation currently is about 3,601 feet, 99 feet from maximum reservoir level. The elevation is projected to continue to drop over the winter months before bottoming out at about 3,598 feet next April. The March, 2013 inflow forecast for April through July, 2013 at Lake Powell is 47 percent of average.

SLCA/IP net generation for Fiscal Year 2013 is 4,216 GWh as compared to 5,607 GWh based on the long-term historical average generation.

Total purchase power expenses for firming during the fiscal year 2013 are about $40 million as compared to about $14.5 million based on long–term median historical releases. Purchase power availability in the region is abundant and prices are reasonable for this time of year.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 16.058 MAF (16.058 MAF Jan-2013), 21.086 MAF (73-Year Historical Avg).

The Lake Mead end of February 2013 elevation was 1,122.14 ft. (.18 ft. lower than end of Jan 2013 elevation ), or about 97.5 ft. below full storage elevation of 1,219.64 ft. and 72.14 ft. above the minimum generation elevation for Hoover of 1,050 ft.

Lake Mead’s elevation peaked at 1122.32 ft in January of WY 2013 (11.86 ft. below the WY 2012 peak elevation of 1134.18 ft.), and is projected to drop to a minimum elevation of 1104.18 ft. in September of WY 2013, a maximum fluctuation in lake elevation of 18.14 ft.

The Lake Powell operational tier for WY 2013 is currently the Upper Elevation Balancing Tier. Total releases from Lake Powell are projected to be average at 8.23 MAF for WY 2013 (actual of 9.47 MAF for WY 2012). The projected 2013 April – July unregulated inflow into Lake Powell is 3.4 MAF or 47% of average (actual of 2.06 MAF or 29% of average for 2012).

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for February 2013 was 70 KAF. The projected side inflow into Lake Mead for WY2013 is 786 KAF which represents a 7% increase over last year’s actual of 732 KAF, and represents 60% of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2013 Generation: 5246 GWh compared to 5643 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2013 is 93% of the average historical generation.

Wholesale Power Market Conditions: The February market prices in the Desert Southwest averaged about $32/MWh firm on-peak, $27/MWh firm off-peak compared to $32/MWh firm on- peak, $25/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 7.889 million-acre-feet, compared to 8.073 MAF last year. Accumulated inflow for the water year-to-date is 87 percent of the 15-year average for Trinity, 81 percent for Shasta, 94 percent for Folsom and 79 percent for New Melones. Reservoir releases are being cut to conserve storage.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. This water year started out with October recorded precipitation totaling 2.70 inches, which is below average for this month. November recorded precipitation totaled 13.00 inches, which is more than 200 percent of average. December came in at 17.10 inches, or 193 percent of average. January came in at 1.50 inches or 17 percent of its average. It ranks as one of the sixth driest. February ended at 0.90 inches or 11 percent of its average. At this point in March, we are only at 3.30 inches of 49 percent of its average. The cumulative total at this time is 38,50 inches or 77 percent of the total average of 50.30 inches.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak April 1st. Therefore, snow water equivalents are reported as a percentage of this average. As of March 21st, the North is at 60 percent, the Central is at 60 percent and the South is at 46 percent of this average. The Sacramento River Index forecast of water supply based upon March 1st conditions is “below normal” for the 90 percent exceedence case and “below normal” for the 50 percent case, reflecting the poor January and February, which have highest averages of the winter months.

The average projection of net generation is again taken from the latest modeling using the update to our customers’ “Green Book.” This average, at 3.34 GWh, is less than the 3.63 GWh from the CVPIA PEIS planning studies. Under the Post 2004 Marketing Plan, net generation, after Project Use load, First Preference Customer load and sub-control area reserve requirement, becomes the Base Resource which is allocated among the Base Resource, Variable Resource and Full Load Service Customers. This past fiscal ended at 109 percent of that average. Reclamation forecasts are based upon December 1st conditions, which were based upon water supply forecast of “dry” for the 90 percent exceedence and “below normal” for the 50 percent exceedence. These forecasts would be 89 percent and 104 percent of this “Green Book” average net generation. Subsequent forecasts appear to be overly optimistic near term based upon current daily allocations of base resource. Hydro Conditions and Purchase Power Monthly Outlook April 2013

Western Summary

• The most probable forecast of net generation for FY 2013 is 23,327 gigawatt-hours (GWh) or 85 percent of average. October through March generation was 83 percent of average. • The lower level forecast of generation for FY 2013 is 22,309 GWh or 81 percent of average. • The purchased power for FY 2013 is expected to range between 3,669 and 3,924 GWh. • The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $45/MWh. This price compares to $50/MWh last year. • Purchase power expenses for FY 2013 are forecast to range between $166 and $175 million. • October through March purchases totaled over $117 million – compared to $56 million for the same period last year.

Upper Great Plains Region

Storage: Based upon a 30 year average, streamflows into Canyon Ferry were 92 percent of average during March. Storage in Canyon Ferry is at 102 percent of average and the anticipated inflows during the April through July period is forecast to be 77 percent of average. Based upon the current water supply forecast, releases out of Canyon Ferry to the Missouri River below Holter Dam will be maintained near 4,000 cfs to assure the reservoir of filling to the top of the joint-use pool by the end of June. Streamflows into Bighorn Lake during March continued to remain below average at only 74% of average. Based on the April 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the April through July runoff into Bighorn Lake is expected to equal 661,000 acre-feet (60% of average).

As of April, 2013, the storage level at Canyon Ferry was 1,451,689 acre feet and the active conservation pool is 76.7% full. Storage at Yellowtail is 847,181 acre feet and the active conservation pool is 85.7% full.

Snow pack: The April 1 forecasted runoff for calendar year 2013 is 20.5 MAF. This runoff would be 81% of normal runoff. As of April 1, 2013, the mountain snowpack in the reach above Fort Peck is 90% of the average snowpack for this date. Mountain snowpack in the reach between Fort Peck and Garrison is 84% of the average snowpack for this date.

FY Generation: The six main stem power plants generated 557 million kilowatt hours of electricity in February. Total energy production for 2013 was earlier forecasted to reach 8.0 billion kWh, but has been reduced to around 7.8 billion KWh. The long-term average is approximately 10 billion kWh.

Purchased Power: Generally prices are staying within the mid twenties for off peak power and mid- to upper-thirties for on peak power.

Rocky Mountain Region

Drought conditions have improved somewhat in the LAP area with recent spring storms but still range from moderate to extreme. The reservoir inflow has been well below normal in all three LAP basins so far this year. The accumulated snowpack at the beginning of the month was below average in the Bighorn Basin and well below average in the North Platte Basin and the Colorado River headwaters. The reservoir storage at the end of March was above average in the Bighorn Basin, below average in the North Platte Basin, and well below average for the Colorado-Big Thompson Project (CBT). The reservoir storage was less than it was at the end of last March in all three basins. The latest National Weather Service forecast for the May through July period indicates temperatures are more likely to be above average and precipitation more likely to be below average in Wyoming and Colorado. Reclamation is forecasting well below average spring reservoir inflows based on snowpack and other factors with the inflow to Seminoe Reservoir forecast to be especially low.

LAP Water Conditions At-A-Glance

Reservoir Storage Snowpack Most Probable Reservoir Inflow 1,000 acre-feet inches snow water equivalent 1,000 acre-feet (April - July) end of % of end of % of April % of March average average March average average forecast average average

CBT 458.5 599.1 77% 312.2 403.3 77% 399.0 590.0 68%

North Platte 1,248.6 1,523.6 82% 295.6 375.9 79% 210.0 750.0 28%

Bighorn 1,840.3 1,713.5 107% 309.6 359.8 86% 908.0 1,435.3 63%

TOTAL 3,547.4 3,836.2 92% 917.4 1,139.0 81% 1,517.0 2,775.3 55%

Net At Plant Generation Projections (GWh)

Most Probable Case Reasonable Minimum Case Reasonable Maximum Case median inflow lower decile inflow upper decile inflow April % of April % of April % of projection average average projection average average projection average average

Winter 12-13 512.8 724.0 71% 512.8 724.0 71% 512.8 724.0 71%

Summer 13 910.0 1,214.7 75% 720.7 1,214.7 59% 1,252.5 1,214.7 103%

TOTAL 2013 1,422.8 1,938.7 73% 1,233.5 1,938.7 64% 1,765.3 1,938.7 91%

LAP generation was well below average over the winter. LAP generation is now expected to be below average through the end of the year. Based on reservoir inflow forecasts and an expected low water quota declaration, Reclamation is now considering a four to six week curtailment of Adams Tunnel imports and associated CBT generation this summer as a means to improve the water clarity of Grand Lake by minimizing the introduction of suspended sediment and organic matter from Shadow Mountain Reservoir to the clearer Grand Lake waters.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 15,975,000 acre feet, which is about 52 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (March 2013) were about 55 percent of average. Lake Powell elevation currently is about 3,598 feet, 102 feet from maximum reservoir level, and about 108 feet from the minimum generation level. The elevation is projected to level out at about 3,598 feet in April, before increasing slightly due to spring runoff. The April, 2013 inflow forecast for April through July, 2013 at Lake Powell is 38 percent of average at 2.7 million acre feet.

Consistent with Section 6.C.1 of the Interim Guidelines, if the August 24-Month study projects the January 1, 2014, Lake Powell elevation to be less than 3,575.0 feet and at or above 3,525.0 feet and the Lake Mead elevation to be at or above 1,025.0 feet, the operational tier for Lake Powell in water year 2014 will be the Mid-Elevation Release Tier and the water year release volume from Lake Powell will be 7.48 maf. This April 2013 24-Month study projects that, with an 8.23 maf annual release pattern in water year 2014, the January 1, 2014, Lake Powell elevation would be 3,573.66 feet and the Lake Mead elevation would be 1,107.60 feet. Therefore, the 2014 Lake Powell operational tier is currently projected to be the Mid-Elevation Release Tier with an annual release volume of 7.48 maf. Based on analysis of a range of inflow scenarios, the current probability of realizing an inflow volume that would result in the Mid-Elevation Release Tier and a 7.48 maf annual release from Lake Powell in 2014 is approximately 65 percent.

SLCA/IP net generation for Fiscal Year 2013 is 4,208 GWh as compared to 5,607 GWh based on the long-term historical average generation.

Total purchase power expenses for firming during the fiscal year 2013 are about $44 million as compared to about $14.5 million based on long–term median historical releases. Purchase power availability in the region is abundant and prices are reasonable for this time of year. Firming purchases for the last couple of months have been in the lower $30’s on peak and upper $20’s off peak. On peak prices are projected to rise into the $40’s as temperatures increase later in the year.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 15.710 MAF (16.058 MAF Feb-2013), 20.894 MAF (73-Year Historical Avg).

The Lake Mead end of March 2013 elevation was 1,118.59 ft. (3.55 ft. lower than end of Feb 2013 elevation ), or about 101.05 ft. below full storage elevation of 1,219.64 ft. and 68.59 ft. above the minimum generation elevation for Hoover of 1,050 ft.

The Lake Powell operational tier for WY 2013 is currently the Upper Elevation Balancing Tier. Total releases from Lake Powell are projected to be average at 8.23 MAF for WY 2013 (actual of 9.47 MAF for WY 2012). The projected 2013 April – July unregulated inflow into Lake Powell is 2.7 MAF or 38% of average (actual of 2.06 MAF or 29% of average for 2012).

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for March 2013 was 67 KAF. The projected side inflow into Lake Mead for WY2013 is 775 KAF which represents a 6% increase over last year’s actual of 732 KAF, and represents 60% of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2013 Generation: 5202 GWh compared to 5644 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2013 is 92% of the average historical generation.

Wholesale Power Market Conditions: The March market prices in the Desert Southwest averaged about $33/MWh firm on-peak, $27/MWh firm off-peak compared to $32/MWh firm on-peak, $27/MWh firm off-peak for the previous month. Sierra Nevada Region

The total storage of the four major CVP reservoirs is 8. 228 million-acre-feet, compared to 9.286 MAF last year. Accumulated inflow for the water year-to-date is 86 percent of the 15-year average for Trinity, 78 percent for Shasta, 83 percent for Folsom and 72 percent for New Melones. Reservoir releases have increased to meet instream flow requirements.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak April 1st. Therefore, snow water equivalents are reported as a percentage of this average. As of April 18th, the North is at 35 percent, the Central is at 46 percent and the South is at 22 percent of this average. The Sacramento River Index forecast of water supply based upon April 1st conditions is “dry” (close to critical) for the 90 percent exceedence case and “dry” for the 50 percent case, reflecting the poor January, February and March, which has set records, but not in a good way. The State’s final yeartype declaration is based upon May 1st conditions at the 50 percent exceedence level.

The average projection of net generation is again taken from the latest modeling using the update to our customers’ “Green Book.” This average, at 3.34 GWh, is less than the 3.63 GWh from the CVPIA PEIS planning studies. Under the Post 2004 Marketing Plan, net generation, after Project Use load, First Preference Customer load and sub-control area reserve requirement, becomes the Base Resource which is allocated among the Base Resource, Variable Resource and Full Load Service Customers. This past fiscal ended at 109 percent of that average. Reclamation forecasts are based upon March 1st conditions, which were based upon water supply forecast of “below normal” (close to dry) for the 90 percent exceedence and “below normal” for the 50 percent exceedence. These forecasts would be 91 percent and 85 percent of this “Green Book” average net generation. The forecasts sometimes “flip” because during drier conditions, more reservoir releases must be made to meet instream flow while under the “less dry” case, some instream flow requirements could conceivably be met via side flows. Project use pumping remains low due to Vernalis Adaptive Management Plan (VAMP) actions and with increased releases on the Sacramento and Stanislaus rivers to meet instream flow requirements, base resource is quite high at this time, but not as high as the forecasted amounts. Hydro Conditions and Purchase Power Monthly Outlook May 2013

Western Summary

• The most probable forecast of net generation for FY 2013 is 22,820 gigawatt-hours (GWh) or 84 percent of average. October through April generation was 85 percent of average. • The lower level forecast of generation for FY 2013 is 22,476 GWh or 83 percent of average. • The purchased power for FY 2013 is expected to range between 3,809 and 4,058 GWh. • The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $43/MWh. This price compares to $51/MWh last year. • Purchase power expenses for FY 2013 are forecast to range between $163 and $175 million. • October through April purchases totaled over $125 million – compared to $66 million for the same period last year.

Upper Great Plains Region

Storage: April brought increased precipitation in the mountains, while streamflows into Canyon Ferry were 73 percent of average due to cooler temperatures. Storage in Canyon Ferry is at 98 percent of average and the anticipated inflows during the May through July period is forecast to be 79 percent of average. Based upon the current water supply forecast, releases out of Canyon Ferry to the Missouri River below Holter Dam will be maintained near 4,000 cfs to assure the reservoir of filling to the top of the joint-use pool by the end of June. Streamflows into Bighorn Lake during April continued to remain below average at only 67% of average. Based on the May 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the May through July runoff into Bighorn Lake is expected to equal 579,000 acre-feet (61% of average).

As of June 2, 2013, the storage level at Canyon Ferry was 1,516,893 acre feet and the active conservation pool is 80.2% full. Storage at Yellowtail is 933,412 acre feet and the active conservation pool is 91.5% full.

Snow pack: The June 1 forecasted runoff for calendar year 2013 is 20.5 MAF. This runoff would be 81% of normal runoff. As of June 1, 2013, the mountain snowpack in the reach above Fort Peck is 93% of the average snowpack for this date. Mountain snowpack in the reach between Fort Peck and Garrison is 92% of the average snowpack for this date.

FY Generation: The six main stem power plants generated 608 million kilowatt hours of electricity in April. Total energy production for 2013 was earlier forecasted to reach 8.0 billion kWh, but has been reduced to around 7.8 billion KWh. The long-term average is approximately 10 billion kWh.

Purchased Power: Generally prices are staying within the mid twenties for off peak power and mid- to upper-thirties for on peak power.

Rocky Mountain Region

Drought conditions have improved somewhat in the LAP area with recent spring storms but still range from moderate to extreme. The reservoir inflow has been well below normal in all three LAP basins so far this year. In a dramatic reversal since last month, the accumulated snowpack at the beginning of this month was near average in the Bighorn Basin and the Colorado River headwaters. It was still below average in the North Platte Basin but well above last year’s level. The reservoir storage at the end of April was still above average in the Bighorn Basin but well below average in the North Platte Basin and for the Colorado-Big Thompson Project (CBT). The snow melt runoff is just beginning. The latest National Weather Service forecast for the May through July period indicates temperatures are more likely to be above average and precipitation more likely to be below average in Wyoming and Colorado. Reclamation is still forecasting well below average spring reservoir inflows but those forecasts are significantly higher than they were last month.

LAP Water Conditions At-A-Glance

Reservoir Storage Snowpack Most Probable Reservoir Inflow 1,000 acre-feet inches snow water equivalent 1,000 acre-feet (April - July) end of % of end of % of May % of April average average April average average forecast average average

CBT 467.2 599.6 78% 364.1 369.5 99% 525.5 590.0 89%

North Platte 1,287.3 1,592.9 81% 359.6 393.5 91% 450.0 750.0 60%

Bighorn 1,824.2 1,668.4 109% 352.8 334.9 105% 998.0 1,435.3 70%

TOTAL 3,578.7 3,860.9 93% 1,076.5 1,097.9 98% 1,973.5 2,775.3 71%

Net At Plant Generation Projections (GWh)

Most Probable Case Reasonable Minimum Case Reasonable Maximum Case median inflow lower decile inflow upper decile inflow May % of May % of May % of projection average average projection average average projection average average

Winter 12-13 512.8 724.0 71% 512.8 724.0 71% 512.8 724.0 71%

Summer 13 1,088.9 1,214.7 90% 904.7 1,214.7 74% 1,299.0 1,214.7 107%

TOTAL 2013 1,601.7 1,938.7 83% 1,417.5 1,938.7 73% 1,811.8 1,938.7 93%

LAP generation was well below average over the winter and in April. LAP generation is still expected to be below average for the upcoming summer season as a whole but much closer to average than was forecast last month. Generation is projected to be above average in June and near average in July and August. The August projection even includes the likely cessation of CBT Adams Tunnel imports to improve water clarity in Grand Lake by minimizing the introduction of organic and non-organic particulates from Shadow Mountain Reservoir.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 15,790,000 acre feet, which is about 51 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (April, 2013) were about 38 percent of average. Lake Powell elevation currently is about 3,596 feet, 104 feet from maximum reservoir level, and about 106 feet from the minimum generation level. The elevation is projected to increase about 5 feet to 3600 by June, then resume declining. The April, 2013 inflow forecast for April through July, 2013 at Lake Powell is 42 percent of average at 3.0 million acre feet.

Consistent with Section 6.C.1 of the Interim Guidelines, if the August 2013 24-Month study projects the January 1, 2014, Lake Powell elevation to be at or above 3,575.00 feet and below the equalization level of 3648.00 feet and the Lake Mead elevation to be at or above 1,075.00 feet, the operational tier for Lake Powell in water year 2014 will be the Upper Elevation Balancing Tier and the water year release volume from Lake Powell will be 8.23 maf. This May 2013 24-Month study projects that, with an 8.23 maf annual release pattern in water year 2014, the January 1, 2014 Lake Powell elevation would be 3,577.27 feet and the Lake Mead elevation would be 1,107.47 feet. Therefore, the 2014 Lake Powell operational tier is currently projected to be the Upper Elevation Balancing Tier with an annual release volume of 8.23 maf and no projected shift in April to the Equalization Tier.

However, if hydrology should become slightly drier than is currently projected and the August 24- Month Study projects the January 1, 2013 Lake Powell elevation to be less than 3,575.00 feet, the Mid-Elevation Release Tier will govern and the annual release volume from Lake Powell will be 7.48 maf. Based on analysis of a range of inflow scenarios, the current probability of realizing an inflow volume that would result in the Upper Elevation Balancing Tier and an 8.23 maf annual release is approximately 55 percent and the probability for the Mid-Elevation Release Tier and a 7.48 maf annual release is approximately 45 percent.

SLCA/IP net generation for Fiscal Year 2013 is 4,233 GWh as compared to 5,607 GWh based on the long-term historical average generation.

Total purchase power expenses for firming during the fiscal year 2013 are about $46 million as compared to about $14.5 million based on long–term median historical releases. Purchase power availability in the region is abundant and prices are reasonable for this time of year. Firming purchases for the last couple of months have been in the lower $30’s on peak and upper $20’s off peak. On peak prices are projected to rise into the $40-50 range as temperatures increase this summer.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 15.231 MAF (15.710 MAF Mar-2013), 20.734 MAF (73-Year Historical Avg).

The Lake Mead end of April 2013 elevation was 1,112.91 ft. (5.68 ft. lower than end of Mar 2013 elevation ), or about 106.73 ft. below full storage elevation of 1,219.64 ft. and 62.91 ft. above the minimum generation elevation for Hoover of 1,050 ft.

Lake Mead’s elevation peaked at 1122.32 ft in January of WY 2013 (11.86 ft. below the WY 2012 peak elevation of 1134.18 ft.), and is projected to drop to a minimum elevation of 1104.23 ft. in September of WY 2013, a maximum fluctuation in lake elevation of 18.09 ft.

The Lake Powell operational tier for WY 2013 is currently the Upper Elevation Balancing Tier. Total releases from Lake Powell are projected to be average at 8.23 MAF for WY 2013 (actual of 9.47 MAF for WY 2012). The projected 2013 April – July unregulated inflow into Lake Powell is 3.0 MAF or 42% of average (actual of 2.06 MAF or 29% of average for 2012).

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for March 2013 was 38 KAF. The projected side inflow into Lake Mead for WY2013 is 735 KAF which represents a 0.7% increase over last year’s actual of 730 KAF, and represents 56% of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2013 Generation: 5189 GWh compared to 5644 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2013 is 92% of the average historical generation.

Wholesale Power Market Conditions: The April market prices in the Desert Southwest averaged about $37/MWh firm on-peak, $29/MWh firm off-peak compared to $33/MWh firm on-peak, $27/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 7.590 million-acre-feet, compared to 9.515 MAF last year. Accumulated inflow for the water year-to-date is 72 percent of the 15-year average for Trinity, 72 percent for Shasta, 73 percent for Folsom and 62 percent for New Melones. Reservoir releases have increased to meet Delta needs.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. This water year started out with October recorded precipitation totaling 2.70 inches, which is below average for this month. November recorded precipitation totaled 13.00 inches, which is more than 200 percent of average. December came in at 17.10 inches, or 193 percent of average. January came in at 1.50 inches or 17 percent of its average. It ranks as one of the sixth driest. February ended at 0.90 inches or 11 percent of its average. March ended at only at 4.38 inches or 65 percent of its average. April ended at 1.52 inches or 41 percent of its average. The cumulative total at this time is 42.00 inches or 83 percent of the total average of 50.30 inches.

The snowpack is assumed to reach its peak April 1st. Therefore, snow water equivalents are reported as a percentage of this average. As of May 23rd, the North is at 2 percent, the Central is at 2 percent and the South is at 1 percent of this average. The Sacramento River Index forecast of water supply based upon May 1st conditions is “dry” (close to critical) for the 90 percent exceedence case and “dry” for the 50 percent case, reflecting the poor January, February and March, which has set records, but not in a good way. The State’s final year type declaration is based upon May 1st conditions at the 50 percent exceedence level. This year is officially “dry.”

The average projection of net generation is again taken from the latest modeling using the update to our customers’ “Green Book.” This average, at 3.34 GWh, is less than the 3.63 GWh from the CVPIA PEIS planning studies. Under the Post 2004 Marketing Plan, net generation, after Project Use load, First Preference Customer load and sub-control area reserve requirement, becomes the Base Resource which is allocated among the Base Resource, Variable Resource, and Full Load Service Customers. This past fiscal year ended at 109 percent of that average. Reclamation forecasts are based upon April 1st conditions, which were based upon water supply forecast of “dry” for the 90 percent exceedence and “dry” for the 50 percent exceedence. These forecasts would be 93 percent and 84 percent of this “Green Book” average net generation. The forecasts sometimes “flip” because during drier conditions, more reservoir releases must be made to meet instream flow while under the “less dry” case, some instream flow requirements could conceivably be met via side flows. Project use pumping remains low due to Delta water quality concerns and with increased releases on the Sacramento to meet Delta needs and increased Trinity River Diversions to support the Sacramento, base resource remains quite high. Hydro Conditions and Purchase Power Monthly Outlook June 2013

Western Summary

• The most probable forecast of net generation for FY 2013 is 22,949 gigawatt-hours (GWh) or 84 percent of average. October through May generation was 85 percent of average. • The lower level forecast of generation for FY 2013 is 22,658 GWh or 83 percent of average. • The purchased power for FY 2013 is expected to range between 3,909 and 4,023 GWh. • The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $45/MWh. This price compares to $49/MWh last year. • Purchase power expenses for FY 2013 are forecast to range between $177 and $182 million. • October through May purchases totaled over $141 million – compared to $72 million for the same period last year.

Upper Great Plains Region

Storage: May inflows resulted in 65 percent of average and the anticipated inflow during the June through July period is forecast to be 52 percent of average. Based upon the current water supply forecast, releases out of Canyon Ferry to the Missouri River below Holter Dam will be maintained near 3,000 cfs to conserve storage. Streamflows into Bighorn Lake during May l continued to remain below average at only 68% of average. Based on the June 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the June through July runoff into Bighorn Lake is expected to equal 350,000 acre-feet (51% of average).

As of June 23, 2013, the storage level at Canyon Ferry was 1,649,904 acre feet and the active conservation pool is 87.2% full. Storage at Yellowtail is 993,286 acre feet and the active conservation pool is 97.3% full.

COE: Total runoff for the year is estimated to be only 85% of normal at 21.2 MAF, normal being 25.2 MAF. Forecasted energy production for the calendar year decreased from last month’s forecast by 135 GWh to 7,607 GWh. The COE continues to operate in drought mode.

Snow pack: The June 1 forecasted runoff for calendar year 2013 is 21.2 MAF. This runoff would be 84% of normal runoff. As of June 1, 2013, the mountain snowpack in the reach above Fort Peck is 26% of the average snowpack for this date. Mountain snowpack in the reach between Fort Peck and Garrison is 24% of the normal April 15 peak snowpack.

FY Generation: The six main stem power plants generated 608 million kilowatt hours of electricity in May. Total energy production for 2013 was earlier forecasted to reach 8.0 billion kWh, but has been reduced to around 7.8 billion KWh. The long-term average is approximately 10 billion kWh.

Purchased Power: Generally prices are staying within the mid twenties for off peak power and mid- to upper-thirties for on peak power.

Rocky Mountain Region

Drought conditions still range from moderate to extreme in the LAP area. The reservoir inflow has been below normal in all three LAP basins so far this year. Due to early melting brought about by high temperatures in late May, the majority of the snowpack had melted by the beginning of June with the remaining snowpack well below average in the Bighorn Basin and the North Platte Basin while still above average in the Colorado River headwaters. The reservoir storage at the end of May remained above average in the Bighorn Basin but well below average in the North Platte Basin and for the Colorado-Big Thompson Project (CBT). The latest National Weather Service forecast for the June through August period indicates temperatures are more likely to be above average in Wyoming and Colorado while precipitation is just as likely to be above average as below average. Midway through the spring runoff period, Reclamation is forecasting well below average spring reservoir inflows except for the CBT where near average inflows are forecast.

LAP Water Conditions At-A-Glance

Reservoir Storage Snowpack Most Probable Reservoir Inflow 1,000 acre-feet inches snow water equivalent 1,000 acre-feet (April - July) end of % of end of % of June % of May average average May average average forecast average average

CBT 590.8 688.6 86% 62.6 56.4 111% 563.5 590.0 96%

North Platte 1,412.9 1,754.7 81% 92.6 122.9 75% 350.0 750.0 47%

Bighorn 1,999.2 1,792.3 112% 65.2 112.6 58% 830.7 1,435.3 58%

TOTAL 4,002.9 4,235.6 95% 220.4 291.9 76% 1,744.2 2,775.3 63%

Net At Plant Generation Projections (GWh)

Most Probable Case Reasonable Minimum Case Reasonable Maximum Case median inflow lower decile inflow upper decile inflow June % of June % of June % of projection average average projection average average projection average average

Winter 12-13 512.8 724.0 71% 512.8 724.0 71% 512.8 724.0 71%

Summer 13 1,000.5 1,214.7 82% 936.4 1,214.7 77% 1,131.4 1,214.7 93%

TOTAL 2013 1,513.3 1,938.7 78% 1,449.2 1,938.7 75% 1,644.2 1,938.7 85%

LAP generation has been well below average since October. With the June reservoir inflow forecasts lower than May forecasts, LAP generation is now expected to be near average from mid- June through mid-July and then be below average for the remainder of the year. The projected generation includes the planned cessation of CBT Adams Tunnel imports and associated generation for a six week period from late July through early August to improve water clarity in Grand Lake by minimizing the introduction of organic and non-organic particulates from Shadow Mountain Reservoir.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 16,344,000 acre feet, which is about 53 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (May, 2013) were about 51 percent of average. Lake Powell elevation currently is about 3,600 feet, 100 feet from maximum reservoir level, and about 110 feet from the minimum generation level. The June, 2013 inflow forecast for April through July 2013 at Lake Powell is 40 percent of average at 2.9 million acre feet.

Consistent with Section 6.C.1 of the Interim Guidelines, if the August 24-Month study projects the January 1, 2014, Lake Powell elevation to be less than 3,575.0 feet and at or above 3,525.0 feet and the Lake Mead elevation to be at or above 1,025.0 feet, the operational tier for Lake Powell in water year 2014 would be the Mid-Elevation Release Tier and the water year release volume from Lake Powell would be 7.48 maf. This June 2013 24-Month study projects that, with an 8.23 maf annual release pattern in water year 2014, the January 1, 2014, Lake Powell elevation would be 3,577.05 feet and the Lake Mead elevation would be 1,105.27 feet. Therefore, the 2014 Lake Powell operational tier is currently projected to be the Upper Elevation Balancing Tier. However, based on analysis of a range of inflow scenarios, the current probability of realizing an inflow volume that would result in the Mid-Elevation Release Tier in 2014 is approximately 45 percent.

SLCA/IP net generation for Fiscal Year 2013 is 4,260 GWh as compared to 5,607 GWh based on the long-term historical average generation.

Total purchase power expenses for firming during the fiscal year 2013 are about $46.5 million as compared to about $14.5 million based on long-term median historical releases. Purchase power availability in the region is abundant and prices are reasonable for this time of year. Firming purchases for the last couple of months have been in the upper $30’s on peak and upper $20’s off peak. On peak prices are projected to rise into the $40-50 range as temperatures increase this summer.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 14.823 MAF (15.231 MAF Apr-2013), 20.867 MAF (73-Year Historical Avg).

The Lake Mead end of May 2013 elevation was 1,108.36 ft. (4.55 ft. lower than end of Apr 2013 elevation ), or about 111.28 ft. below full storage elevation of 1,219.64 ft. and 58.36 ft. above the minimum generation elevation for Hoover of 1,050 ft.

Lake Mead’s elevation peaked at 1122.32 ft in January of WY 2013 (11.86 ft. below the WY 2012 peak elevation of 1134.18 ft.), and is projected to drop to a minimum elevation of 1103.92 ft. in September of WY 2013, a maximum fluctuation in lake elevation of 18.4 ft.

The Lake Powell operational tier for WY 2013 is currently the Upper Elevation Balancing Tier. Total releases from Lake Powell are projected to be average at 8.23 MAF for WY 2013 (actual of 9.47 MAF for WY 2012). The projected 2013 April – July unregulated inflow into Lake Powell is 3.0 MAF or 42% of average (actual of 2.06 MAF or 29% of average for 2012).

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for April 2013 was 29 KAF. The projected side inflow into Lake Mead for WY2013 is 700 KAF which represents a 4.1% decrease over last year’s actual of 730 KAF, and represents 54% of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2013 Generation: 5179 GWh compared to 5652 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2013 is 92% of the average historical generation.

Wholesale Power Market Conditions: The May market prices in the Desert Southwest averaged about $38/MWh firm on-peak, $26/MWh firm off-peak compared to $37/MWh firm on-peak, $29/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 6.842 million-acre-feet, compared to 8.870 MAF last year. Accumulated inflow for the water year-to-date is 63 percent of the 15-year average for Trinity, 71 percent for Shasta, 68 percent for Folsom and 55 percent for New Melones. Reservoir releases have increased to meet Delta needs. This past weekend, there was a real-time cut to Federal pumping taking it to zero for 24 hours to meet required Delta outflow.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. This water year started out with October recorded precipitation totaling 2.70 inches, which is below average for this month. November recorded precipitation totaled 13.00 inches, which is more than 200 percent of average. December came in at 17.10 inches, or 193 percent of average. January came in at 1.50 inches or 17 percent of its average. It ranks as one of the sixth driest. February ended at 0.90 inches or 11 percent of its average. March ended at only at 4.38 inches or 65 percent of its average. April ended at 1.52 inches or 41 percent of its average. May ended at 1.30 inches or 59 percent of its average. The cumulative total at this time is 42.40 inches or 83 percent of the total average of 50.30 inches. There has been no measurable precipitation for June at this time, but some has been forecast.

The snowpack is assumed to reach its peak April 1st. Therefore, snow water equivalents are reported as a percentage of this average. As of May 23rd, the North is at 2 percent, the Central is at 2 percent and the South is at 1 percent of this average. The Sacramento River Index forecast of water supply based upon May 1st conditions is “dry” (close to critical) for the 90 percent exceedence case and “dry” for the 50 percent case, reflecting the poor January, February and March, which has set records, but not in a good way. The State’s final yeartype declaration is based upon May 1st conditions at the 50 percent exceedence level. This year is officially “dry.”

The average projection of net generation is again taken from the latest modeling using the update to our customers’ “Green Book.” This average, at 3.34 GWh, is less than the 3.63 GWh from the CVPIA PEIS planning studies. Under the Post 2004 Marketing Plan, net generation, after Project Use load, First Preference Customer load and sub-control area reserve requirement, becomes the Base Resource which is allocated among the Base Resource, Variable Resource and Full Load Service Customers. This past fiscal year ended at 109 percent of that average. Reclamation forecasts are based upon April 1st conditions, which were based upon water supply forecast of “dry” for the 90 percent exceedence and “dry” for the 50 percent exceedence. These forecasts would be 93 percent and 90 percent of this “Green Book” average net generation. The forecasts sometimes “flip” because during drier conditions, more reservoir releases must be made to meet instream flow while under the “less dry” case, some instream flow requirements could conceivably be met via side flows. Project use pumping remains low due to Delta water quality concerns and with increased releases on the Sacramento to meet Delta needs and increased Trinity River Diversions to support the Sacramento, base resource remains quite high.

Hydro Conditions and Purchase Power Monthly Outlook July 2013

Western Summary

• The most probable forecast of net generation for FY 2013 is 22,718 gigawatt-hours (GWh) or 84 percent of average. October through June generation was 85 percent of average. • The lower level forecast of generation for FY 2013 is 22,651 GWh or 83 percent of average. • The purchased power for FY 2013 is expected to be approximately 4,126 GWh. • The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $43/MWh. This price compares to $49/MWh last year. • Purchase power expenses for FY 2013 are forecast to be approximately $179 million. • October through June purchases totaled over $146 million – compared to $78 million for the same period last year.

Cumulative of Actual Purchase Power Expenses - FY 13 $200

$175 Most Probable/Actual Dry $150

$125

$100

$75

$50 Millions of Dollars $25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month Upper Great Plains Region

Storage: June inflows resulted in 50 percent of average and the anticipated inflow for July is forecast to be 40 percent of average. Based upon the current water supply forecast, releases out of Canyon Ferry to the Missouri River below Holter Dam will be maintained near 3,000 cfs to conserve storage. Streamflows into Bighorn Lake during June continued to remain below average at only 51% of average. Based on the July 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the July runoff into Bighorn Lake is expected to equal 116,000 acre-feet (44% of average).

As of July 17, 2013, the storage level at Canyon Ferry was 1,654,682 acre feet and the active conservation pool is 87.5% full. Storage at Yellowtail is 1,014,440 acre feet and the active conservation pool is 99.4% full.

Snow pack: The July 1 forecasted runoff for calendar year 2013 is 22.3 MAF. This runoff would be 88% of normal runoff. As of July 1, 2013, the mountain snowpack in the reach above Fort Peck is 24% of the average snowpack for this date. Mountain snowpack in the reach between Fort Peck and Garrison is 24% of the normal April 15 peak snowpack.

FY Generation: The six main stem power plants generated 608 million kilowatt hours of electricity in June. Total energy production for 2013 was earlier forecasted to reach 8.0 billion kWh, but has been reduced to around 7.8 billion KWh. The long-term average is approximately 10 billion kWh.

Purchased Power: With the advent of warmer weather, on peak prices are starting to get to $50 and off peak power holds in the mid to upper twenties.

Rocky Mountain Region

Drought conditions still range from moderate to extreme in the LAP area. The reservoir inflow has been below normal in all three LAP basins so far this year. The snow pack has now melted at all but the highest elevations. The reservoir storage at the end of June was near average in the Bighorn Basin and well below average in the North Platte Basin and for the Colorado-Big Thompson Project (CBT). The latest National Weather Service forecast for the August through October period indicates temperatures are more likely to be above average in Wyoming and Colorado while precipitation is just as likely to be above average as below average. Due to a lack of precipitation in May and June, the spring runoff will end up below average for the CBT and well below average for the North Platte and Bighorn basins.

LAP Water Conditions At-A-Glance

Reservoir Storage Actual Reservoir Inflow To-Date Most Probable Reservoir Inflow 1,000 acre-feet 1,000 acre-feet 1,000 acre-feet (April - July) end of % of October % of July % of June average average - June average average forecast average average

CBT 708.6 797.5 89% 531.1 569.1 93% 540.8 590.0 92%

North Platte 1,335.2 1,886.9 71% 475.7 948.3 50% 328.4 750.0 44%

Bighorn 2,178.3 2,139.1 102% 939.5 1,310.7 72% 729.4 1,435.3 51%

TOTAL 4,222.1 4,823.5 88% 1,946.3 2,828.1 69% 1,598.6 2,775.3 58%

Net At Plant Generation Projections (GWh)

Most Probable Case Reasonable Minimum Case Reasonable Maximum Case median inflow lower decile inflow upper decile inflow July % of July % of July % of projection average average projection average average projection average average

Winter 12-13 512.8 724.0 71% 512.8 724.0 71% 512.8 724.0 71%

Summer 13 939.2 1,214.7 77% 911.0 1,214.7 75% 999.8 1,214.7 82%

TOTAL 2013 1,452.0 1,938.7 75% 1,423.8 1,938.7 73% 1,512.6 1,938.7 78%

LAP generation has been well below average since October. With the July reservoir inflow forecasts lower than June forecasts, LAP generation is now expected to be below average for the remainder of the year. The projected generation includes the planned cessation of CBT Adams Tunnel imports and associated generation for a six week period from July 23rd through August 3rd to improve water clarity in Grand Lake by minimizing the introduction of organic and non-organic particulates from Shadow Mountain Reservoir. The Park Service has determined that recent fires near Grand Lake will not impact the water clarity.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 16,144,000 acre feet, which is about 52 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (June, 2013) were about 34 percent of average. Lake Powell elevation currently is about 3,599 feet, 101 feet from maximum reservoir level, and about 109 feet from the minimum generation level. The July, 2013 inflow forecast for April through July, 2013 at Lake Powell is 37 percent of average at 2.67 million acre feet.

Consistent with Section 6.C.1 of the Interim Guidelines, if the August 24-Month study projects the January 1, 2014, Lake Powell elevation to be less than 3,575.0 feet and at or above 3,525.0 feet and the Lake Mead elevation to be at or above 1,025.0 feet, the operational tier for Lake Powell in water year 2014 will be the Mid-Elevation Release Tier and the water year release volume from Lake Powell will be 7.48 maf. This July 2013 24-Month study projects that, with an 8.23 maf annual release pattern in water year 2014, the January 1, 2014, Lake Powell elevation would be 3,574.97 feet and the Lake Mead elevation would be 1,105.73 feet. Therefore, the 2014 Lake Powell operational tier is currently projected to be the Mid-Elevation Release Tier with an annual release volume of 7.48 maf. Based on analysis of a range of inflow scenarios, the current probability of realizing an inflow volume that would result in the Mid-Elevation Release Tier in 2014 is slightly greater than 50 percent.

SLCA/IP net generation for Fiscal Year 2013 is 4,294 GWh as compared to 5,607 GWh based on the long-term historical average generation.

Total purchase power expenses for firming during the fiscal year 2013 are about $47.6 million as compared to about $14.8 million based on long–term median historical releases. Purchase power availability in the region is abundant and prices are typical for this time of year. Firming purchases for the last couple of months have been in the upper $30’s to low $40’s on-peak and upper $20’s to low $30’s off-peak. Spot Market prices spiked to over $100/MWh on-peak during a particularly hot period at the end of June.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 14.576 MAF (14.823 MAF May-2013), 21.099 MAF (73-Year Historical Avg).

The Lake Mead end of June 2013 elevation was 1,105.98 ft. (2.38 ft. lower than end of May 2013 elevation ), or about 113.66 ft. below full storage elevation of 1,219.64 ft. and 55.98 ft. above the minimum generation elevation for Hoover of 1,050 ft.

Lake Mead’s elevation peaked at 1122.32 ft in January of WY 2013 (11.86 ft. below the WY 2012 peak elevation of 1134.18 ft.), and is projected to drop to a minimum elevation of 1103.84 ft. in September of WY 2013, a maximum fluctuation in lake elevation of 18.48 ft.

The Lake Powell operational tier for WY 2013 is currently the Upper Elevation Balancing Tier. Total releases from Lake Powell are projected to be average at 8.23 MAF for WY 2013 (actual of 9.47 MAF for WY 2012). The projected 2013 April – July unregulated inflow into Lake Powell is 2.67 MAF or 37% of average (actual of 2.06 MAF or 29% of average for 2012).

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for May 2013 was 2 KAF. The projected side inflow into Lake Mead for WY2013 is 669 KAF which represents a 8.4% decrease over last year’s actual of 730 KAF, and represents 51% of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2013 Generation: 5201 GWh compared to 5644 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2013 is 92% of the average historical generation.

Wholesale Power Market Conditions: The June market prices in the Desert Southwest averaged about $38/MWh firm on-peak, $26/MWh firm off-peak compared to $38/MWh firm on-peak, $26/MWh firm off-peak for the previous month. Sierra Nevada Region

The total storage of the four major CVP reservoirs is 5.382 million-acre-feet, compared to 7.887 MAF last year. Accumulated inflow for the water year-to-date is 61 percent of the 15-year average for Trinity, 71 percent for Shasta, 68 percent for Folsom and 53 percent for New Melones. Folsom Reservoir releases are being cut to conserve storage.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. This water year started out with October recorded precipitation totaling 2.70 inches, which is below average for this month. November recorded precipitation totaled 13.00 inches, which is more than 200 percent of average. December came in at 17.10 inches, or 193 percent of average. January came in at 1.50 inches or 17 percent of its average. It ranks as one of the sixth driest. February ended at 0.90 inches or 11 percent of its average. March ended at only at 4.38 inches or 65 percent of its average. April ended at 1.52 inches or 41 percent of its average. May ended at 1.30 inches or 59 percent of its average. June ended at 1.80 inches or 186 percent of its average. The cumulative total at this time is 44.20 inches or 88 percent of the total average of 50.30 inches. There has been no measurable precipitation for July at this time.

The snowpack is assumed to reach its peak April 1st. Therefore, snow water equivalents are reported as a percentage of this average. As of May 23rd, the North is at 2 percent, the Central is at 2 percent and the South is at 1 percent of this average. The Sacramento River Index forecast of water supply based upon May 1st conditions is “dry” (close to critical) for the 90 percent exceedence case and “dry” for the 50 percent case, reflecting the poor January, February and March, which has set records, but not in a good way. The State’s final yeartype declaration is based upon May 1st conditions at the 50 percent exceedence level. This year is officially “dry.”

The average projection of net generation is again taken from the latest modeling using the update to our customers’ “Green Book.” This average, at 3.34 GWh, is less than the 3.63 GWh from the CVPIA PEIS planning studies. Under the Post 2004 Marketing Plan, net generation, after Project Use load, First Preference Customer load and sub-control area reserve requirement, becomes the Base Resource which is allocated among the Base Resource, Variable Resource and Full Load Service Customers. This past fiscal year ended at 109 percent of that average. Reclamation forecasts are based upon April 1st conditions, which were based upon water supply forecast of “dry” for the 90 percent exceedence and “dry” for the 50 percent exceedence. These forecasts would be 93 percent and 94 percent of this “Green Book” average net generation. Forecasts sometimes “flip” because during drier conditions, more reservoir releases must be made to meet demands while under the “less dry” case, some flow requirements could conceivably be met via side flow. Project use pumping is now at maximum to meet South of Delta water demands. Hydro Conditions and Purchase Power Monthly Outlook August 2013

Western Summary

 The most probable forecast of net generation for FY 2013 is 22,722 gigawatt-hours (GWh) or 85 percent of average. October through July generation was 86 percent of average.  The lower level forecast of generation for FY 2013 is 22,686 GWh or 85 percent of average.  The purchased power for FY 2013 is expected to be approximately 4,161 GWh.  The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $42/MWh. This price compares to $48/MWh last year.  Purchase power expenses for FY 2013 are forecast to be approximately $173 million.  October through July purchases totaled over $155 million – compared to $84 million for the same period last year.

Cumulative of Actual Purchase Power Expenses - FY 13 $200

$175 Most Probable/Actual Dry

$150

$125

$100

$75

$50 Millions of Dollars of Millions $25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month Upper Great Plains Region

Storage: July inflows resulted in 42 percent of average and the anticipated inflow for August is forecast to be 52 percent of average. Based upon the current water supply forecast, releases out of Canyon Ferry to the Missouri River below Holter Dam will be maintained near 3,000 cfs to conserve storage. Streamflows into Bighorn Lake during July continued to remain below average at only 50 percent of average. Based on the August 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the August runoff into Bighorn Lake is expected to equal 100,300 acre-feet (66 percent of average).

As of August 19, 2013, the storage level at Canyon Ferry was 1,541,288 acre feet and the active conservation pool is 81.5 percent full. Storage at Yellowtail is 959,760 acre feet and the active conservation pool is 94.0 percent full.

COE: Total runoff for the year is estimated to be 90 percent of normal at 22.7 MAF, due to above normal rains in the Missouri Basin. Up 2 percent from last month. Normal runoff is 25.2 MAF. The COE remains in conservation mode and recent rains below Gavins Point have allowed the COE to lower releases from the system and still keep navigation elevations at usable levels. Forecasted energy production for the calendar year is up slightly from last month’s forecast by 97 GWh.

Snow pack: The August 1 forecasted runoff for calendar year 2013 is 22.7 MAF. This runoff would be 90 percent of normal runoff.

FY Generation: The six main stem power plants generated 726 million kilowatt hours of electricity in July. Total energy production for 2013 was earlier forecasted to reach 8.0 billion kWh, but has been reduced to around 7.8 billion KWh. The long-term average is approximately 10 billion kWh.

Purchased Power: The expected hot weather did not come and cooler temperatures kept the prices in the lower 20s for off peak power and upper 30s for on peak power.

Rocky Mountain Region

Drought conditions still range from moderate to extreme in the LAP area. The reservoir inflow has been below normal in all three LAP basins so far this year. The reservoir storage at the end of July was near average in the Bighorn Basin, below average for the Colorado-Big Thompson Project (CBT), and well below average in the North Platte Basin. The latest National Weather Service forecast for the September through November period indicates temperatures and precipitation are just as likely to be above average as below average. The spring runoff ended up below average for the CBT and well below average for the North Platte and Bighorn basins.

LAP Water Conditions At-A-Glance

Reservoir Storage Actual Reservoir Inflow To-Date Spring Reservoir Inflow 1,000 acre-feet 1,000 acre-feet 1,000 acre-feet (April - July) end of % of October % of % of July average average - July average average actual average average

CBT 696.1 776.4 90% 611.5 697.0 88% 526.1 590.0 89%

North Platte 1,036.8 1,636.5 63% 501.8 1,067.7 47% 356.4 750.0 48%

Bighorn 2,081.6 2,124.4 98% 1,069.7 1,613.0 66% 792.8 1,435.3 55%

TOTAL 3,814.5 4,537.3 84% 2,183.0 3,377.7 65% 1,675.3 2,775.3 60%

Net At Plant Generation Projections (GWh)

Most Probable Case Reasonable Minimum Case Reasonable Maximum Case median inflow lower decile inflow upper decile inflow August % of August % of August % of projection average average projection average average projection average average

Winter 12-13 512.8 724.0 71% 512.8 724.0 71% 512.8 724.0 71%

Summer 13 922.2 1,214.7 76% 916.1 1,214.7 75% 942.5 1,214.7 78%

TOTAL 2013 1,435.0 1,938.7 74% 1,428.9 1,938.7 74% 1,455.3 1,938.7 75%

Winter 13-14 482.1 724.0 67% 464.8 724.0 64% 548.5 724.0 76%

LAP generation has been well below average since October and is expected to be below average through September. The low generation reflects hydrologic conditions, significant plant bypasses for maintenance, and the six week cessation of CBT Adams Tunnel imports and associated generation to improve Grand Lake water clarity that started on July 23. The upcoming winter generation is projected to be well between 64 percent and 76 percent of average depending on the level of late season water demand.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 15,408,000 acre feet, which is about 50 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (July 2013) were about 19 percent of average. Lake Powell elevation currently is about 3,593 feet, 107 feet from maximum reservoir level, and about 103 feet from the minimum generation level. Based on observed inflows and current forecasts, water year 2013 unregulated inflow is expected to be 4.33 MAF (40 percent of average), which would be the second significantly below-average year in a row.

The August 2013 24-Month study projects that, with an 8.23 MAF annual release pattern in water year 2014, the January 1, 2014, Lake Powell elevation would be 3,573.69 feet and the Lake Mead elevation would be 1,107.39 feet. Therefore, consistent with Section 6.C.1 of the Interim Guidelines for the operation of Lake Powell and Lake Mead, the Lake Powell operational tier for water year 2014 is the Mid-Elevation Release Tier with an annual release volume of 7.48 MAF.

Estimated SLCA/IP net generation for Fiscal Year 2013 is 4.29 GWh as compared to 5.61 GWh based on the long-term historical average generation.

Total purchase power expenses for firming during the fiscal year 2013 are about $49.8 million as compared to about $14.8 million based on long–term median historical releases. Purchase power availability in the region is abundant and prices are typical for this time of year. Firming purchases for the last couple of months have been in the upper $30’s to low $40’s on-peak and upper $20’s to low $30’s off-peak.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 14.577 MAF (14.576 MAF June 2013), 20.995 MAF (63-Year Historical Avg).

The Lake Mead end of July 2013 elevation was 1,105.92 ft. (0.06 ft. lower than end of June 2013 elevation ), or about 113.72 ft. below full storage elevation of 1,219.64 ft. and 55.92 ft. above the minimum generation elevation for Hoover of 1,050 ft.

Lake Mead’s elevation peaked at 1122.32 ft in January of WY 2013 (11.86 ft. below the WY 2012 peak elevation of 1134.18 ft.), and is projected to drop to a minimum elevation of 1104.29 ft. in September of WY 2013, a maximum fluctuation in lake elevation of 18.03 ft.

The Lake Powell operational tier for WY 2013 is currently the Upper Elevation Balancing Tier. Total releases from Lake Powell are projected to be average at 8.23 MAF for WY 2013 (actual of 9.47 MAF for WY 2012). The preliminary observed 2013 April – July unregulated inflow into Lake Powell is 2.56 MAF or 36 percent of average (actual of 2.06 MAF or 29 percent of average for 2012).

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for June 2013 was 115 KAF. The projected side inflow into Lake Mead for WY2013 is 728 KAF which represents a 0.3 percent decrease over last year’s actual of 730 KAF, and represents 56 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2013 Generation: 5163 GWh compared to 5643 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2013 is 91 percent of the average historical generation.

Wholesale Power Market Conditions: The July market prices in the Desert Southwest averaged about $44/MWh firm on-peak, $26/MWh firm off-peak compared to $38/MWh firm on-peak, $26/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 5.192 MAF, compared to 6.979 MAF last year. Accumulated inflow for the water year-to-date is 61 percent of the 15-year average for Trinity, 72 percent for Shasta, 68 percent for Folsom and 54 percent for New Melones. Reclamation announced on August 7 that water from the Trinity Reservoir will go to supplement flows in the Lower Klamath River in an effort to help protect an expected large returning run of adult Chinook salmon from a disease outbreak and mortality.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. This water year started out with October recorded precipitation totaling 2.70 inches, which is below average for this month. November recorded precipitation totaled 13.00 inches, which is more than 200 percent of average. December came in at 17.10 inches, or 193 percent of average. January came in at 1.50 inches or 17 percent of its average. It ranks as one of the sixth driest. February ended at 0.90 inches or 11 percent of its average. March ended at only at 4.38 inches or 65 percent of its average. April ended at 1.52 inches or 41 percent of its average. May ended at 1.30 inches or 59 percent of its average. June ended at 1.80 inches or 186 percent of its average. July ended at zero inches. The cumulative total at this time is 44.30 inches or 88 percent of the total average of 50.30 inches. There has been no measurable precipitation for August.

The snowpack is assumed to reach its peak April 1. Therefore, snow water equivalents are reported as a percentage of this average. As of May 23, the North is at 2 percent, the Central is at 2 percent and the South is at 1 percent of this average. The Sacramento River Index forecast of water supply based upon May 1 conditions is “dry” (close to critical) for the 90 percent exceedence case and “dry” for the 50 percent case, reflecting the poor January, February and March, which has set records, but not in a good way. The State’s final yeartype declaration is based upon May 1 conditions at the 50 percent exceedence level. This year is officially “dry.”

The average projection of net generation is again taken from the latest modeling using the update to our customers’ “Green Book.” This average, at 3.34 GWh, is less than the 3.63 GWh from the CVPIA PEIS planning studies. Under the Post 2004 Marketing Plan, net generation, after Project Use load, First Preference Customer load and sub-control area reserve requirement, becomes the Base Resource which is allocated among the Base Resource, Variable Resource and Full Load Service Customers. This past fiscal year ended at 109 percent of that average. Reclamation forecasts are based upon April 1 conditions, which were based upon water supply forecast of “dry” for the 90 percent exceedence and “dry” for the 50 percent exceedence. These forecasts would both be 93 percent of this “Green Book” average net generation. Project use pumping is now at maximum to meet South of Delta water demands. And operations at San Luis Reservoir have changed from generation to pumping. Hydro Conditions and Purchase Power Monthly Outlook September 2013

Western Summary

 The most probable forecast of net generation for FY 2013 is 22,590 gigawatt-hours (GWh) or 83 percent of average. October through August generation was 83 percent of average.  The lower level forecast of generation for FY 2013 is 22,558 GWh or 83 percent of average.  The purchased power for FY 2013 is expected to be approximately 4,338 GWh.  The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $41/MWh. This price compares to $48/MWh last year.  Purchase power expenses for FY 2013 are forecast to be approximately $179.7 million.  October through August purchases totaled over $169 million – compared to $91 million for the same period last year.

Cumulative of Actual Purchase Power Expenses - FY 13 $200

$175 Most Probable/Actual Dry

$150

$125

$100

$75

$50 Millions of Dollars of Millions $25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep

Month

Upper Great Plains Region

Storage: August inflows resulted in 51 percent of average and the anticipated inflow for September is forecast to be 57 percent of average. Based upon the current water supply forecast, releases out of Canyon Ferry to the Missouri River below Holter Dam will be maintained near 3,000 cfs to conserve storage. Streamflows into Bighorn Lake during August continued to remain below average at only 64% of average. Based on the September 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the September runoff into Bighorn Lake is expected to equal 122,700 acre-feet (66% of average).

As of September 22, 2013, the storage level at Canyon Ferry was 1,451,091 acre feet and the active conservation pool is 76.7% full. Storage at Yellowtail is 946,501 acre feet and the active conservation pool is 92.7% full.

COE: Total runoff for the year is estimated to be 90% of normal at 22.7 million acre-feet (MAF), due to above normal rains in the Missouri Basin. Up 2% from last month. Normal runoff is 25.2 MAF. The COE remains in conservation mode and recent rains below Gavins Point have allowed the COE to lower releases from the system and still keep navigation elevations at usable levels. Forecasted energy production for the calendar year is up slightly from last month’s forecast by 97 GWh.

Snow pack: The September 1 forecasted runoff for calendar year 2013 is 22.7 MAF. This runoff would be 90% of normal runoff.

FY Generation: The six main stem power plants generated 726 million kilowatt hours of electricity in July. Total energy production for 2013 was earlier forecasted to reach 8.0 billion kWh, but has been reduced to around 7.6 billion KWh. The long-term average is approximately 10 billion kWh.

Purchased Power: Surplus energy and cooler fall temperatures depressed the market prices to low to mid-teens for off peak power and low to mid-twenties for on peak power.

Rocky Mountain Region

Drought conditions still range from moderate to extreme in most of the LAP area. Parts of the South Platte, North Platte, and Upper Colorado rivers are no longer in drought status due to record precipitation that caused September flooding. The reservoir inflow has been well below normal in all three LAP basins so far this year. The reservoir storage at the end of August was near average in the Bighorn Basin, below average for the Colorado-Big Thompson Project (CBT), and well below average in the North Platte Basin. The latest National Weather Service forecast for the October through December period indicates temperatures are more likely to be above normal in southwest Colorado and southwest Wyoming and just as likely to be above normal as below normal elsewhere. Precipitation is just as likely to be above normal as below normal throughout the LAP area.

LAP Water Conditions At-A-Glance

Reservoir Storage Actual Reservoir Inflow To-Date Spring Reservoir Inflow 1,000 acre-feet 1,000 acre-feet 1,000 acre-feet (April - July) end of % of October % of % of August average average - August average average actual average average

CBT 628.5 718.9 87% 648.7 754.6 86% 526.1 590.0 89%

North Platte 781.2 1,343.7 58% 519.6 1,110.0 47% 356.4 750.0 48%

Bighorn 1,912.4 1,988.1 96% 1,122.7 1,712.5 66% 792.8 1,435.3 55%

TOTAL 3,322.1 4,050.7 82% 2,291.0 3,577.1 64% 1,675.3 2,775.3 60%

Net At Plant Generation Projections (GWh)

Most Probable Case Reasonable Minimum Case Reasonable Maximum Case median inflow lower decile inflow upper decile inflow September % of September % of September % of projection average average projection average average projection average average

Winter 12-13 512.8 724.0 71% 512.8 724.0 71% 512.8 724.0 71%

Summer 13 911.0 1,214.7 75% 909.0 1,214.7 75% 912.1 1,214.7 75%

TOTAL 2013 1,423.8 1,938.7 73% 1,421.8 1,938.7 73% 1,424.9 1,938.7 73%

Winter 13-14 483.3 724.0 67% 468.3 724.0 65% 515.0 724.0 71%

LAP generation has been well below average since October and is also expected to be below average in September. The low generation reflects hydrologic conditions, significant plant bypasses for maintenance, and the six week cessation of CBT Adams Tunnel imports and associated generation to improve Grand Lake water clarity that started on July 23 and ended on September 4. The upcoming winter generation is projected to be between 65% and 70% of average depending on the level of late season water demand.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 15,051,000 acre feet, which is about 49 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (August, 2013) were about 54 percent of average. Lake Powell elevation currently is about 3,590 feet, 110 feet from maximum reservoir level, and about 100 feet from the minimum generation level. Based on observed inflows and current forecasts, water year 2013 unregulated inflow is expected to be 4.46 MAF (41% of average), which would be the second significantly below-average year in a row.

The hydrologic forecast for water year 2014 for Lake Powell, issued by the Colorado Basin River Forecast Center, projects that the most probable (median) unregulated inflow volume will be 8.41 MAF (78% of average based on the period 1981-2010). The Lake Powell operational tier for water year 2014 is the Mid-Elevation Release Tier with an annual release volume of 7.48 MAF.

Estimated SLCA/IP net generation for Fiscal Year 2013 is 4.28 GWh as compared to 5.61 GWh based on the long-term historical average generation.

Total purchase power expenses for firming during the fiscal year 2013 are about $52.4 million as compared to about $14.8 million based on long–term median historical releases. Purchase power availability in the region is abundant and prices are typical for this time of year. Firming purchases for the last couple of months have been in the upper $30’s to low $40’s on-peak and upper $20’s to low $30’s off-peak.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 14.629 MAF (14.577 MAF July-2013), 20.860 MAF (63-Year Historical Avg).

The Lake Mead end of August 2013 elevation was 1,106.13 ft. (0.21 ft. higher than end of July 2013 elevation ), or about 113.51 ft. below full storage elevation of 1,219.64 ft. and 56.13 ft. above the minimum generation elevation for Hoover of 1,050 ft.

Lake Mead’s elevation peaked at 1122.32 ft in January of WY 2013 (11.86 ft. below the WY 2012 peak elevation of 1134.18 ft.), and is projected to drop to a minimum elevation of 1106.16 ft. in September of WY 2013, a maximum fluctuation in lake elevation of 16.16 ft.

The Lake Powell operational tier for WY 2013 is currently the Upper Elevation Balancing Tier. Total releases from Lake Powell are projected to be average at 8.23 MAF for WY 2013 (actual of 9.47 MAF for WY 2012). The observed 2013 April – July unregulated inflow into Lake Powell was 2.56 MAF or 36% of average (actual of 2.06 MAF or 29% of average for 2012).

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for Aug 2013 was 129 KAF. The projected side inflow into Lake Mead for WY 2013 is 747 KAF which represents a 2.3% increase over last year’s actual of 730 KAF, and represents 57% of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2013 Generation: 5,076 GWh compared to 5,642 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2013 is 90% of the average historical generation.

Wholesale Power Market Conditions: The August market prices in the Desert Southwest averaged about $37/MWh firm on-peak, $26/MWh firm off-peak compared to $44/MWh firm on-peak, $26/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 4.684 MAF, compared to 6.426 MAF last year. Accumulated inflow for the water year-to-date is 61 percent of the 15-year average for Trinity, 72 percent for Shasta, 68 percent for Folsom and 55 percent for New Melones.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. This water year started out with October recorded precipitation totaling 2.70 inches, which is below average for this month. November recorded precipitation totaled 13.00 inches, which is more than 200 percent of average. December came in at 17.10 inches, or 193 percent of average. January came in at 1.50 inches or 17 percent of its average. It ranks as one of the sixth driest. February ended at 0.90 inches or 11 percent of its average. March ended at only at 4.38 inches or 65 percent of its average. April ended at 1.52 inches or 41 percent of its average. May ended at 1.30 inches or 59 percent of its average. June ended at 1.80 inches or 186 percent of its average. July ended at zero inches. August ended at zero inches. September has 1.24 inches of recorded precipitation which is 156 percent of its monthly average. The cumulative total at this time is 45.54 inches or 91 percent of the total average of 50.30 inches.

Hydro Conditions and Purchase Power Report October 2013

Western Summary

 Fiscal year (FY) 2013 ended with net generation of 22,511 gigawatt-hours (GWh) or 83 percent of average.  The amount of power purchased for FY 2013 was 4,428 GWh compared to FY 2012 purchases of 2,112 GWh.  The average price for purchase power across all hydro projects and off-peak and on-peak periods was $41/megawatt-hour (MWh). This price compares to $47/MWh last year.  Purchase power expenses for FY 2013 were $181.5 million, compared to $100.3 million for FY 2012. The breakdown for the FY 2013 purchases, in millions, is: UGPR - $47.8, RMR - $27, CRSP - $52.4, DSW - $3.1, and SNR - $51.2.

Cumulative of Actual Purchase Power Expenses - FY 13 $200

$175

Most Probable/Actual

$150

$125

$100

$75

$50 Millions of Dollars of Millions $25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month

Upper Great Plains Region

Storage: September inflows resulted in 65 percent of average and the anticipated inflow for October is forecast to be 85 percent of average. Based upon the current water supply forecast, releases out of Canyon Ferry to the Missouri River below Holter Dam will be maintained near 2,900 cfs to conserve storage. Due to frequented precipitation events, streamflows into Bighorn Lake during September improved to 96 percent of average. Based on the October 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the October runoff into Bighorn Lake is expected to equal 146,600 acre-feet (90 percent of average.

As of September 28, 2013, the storage level at Canyon Ferry was 1,471,193 acre feet and the active conservation pool is 77.8 percent full. Storage at Yellowtail is 1,023,225 acre feet and the active conservation pool is 100.0 percent full.

COE: Total runoff for the year is estimated to be 91 percent of normal at 23.1 MAF, due to above normal rains in the Missouri Basin. There has been very little change to the Missouri River system over the summer, up approximately one percent. The COE remains in conservation mode and are being determined by river levels for navigation in the Kansas City area. Dry conditions along the Missouri River are keeping releases at Gavins Point relatively high and steady, but has been as predicted by COE. Forecasted energy production for the calendar year remained unchanged.

Snow pack: The September 1 forecasted runoff for calendar year 2013 is 22.7 million acre-feet (MAF). This runoff would be 90 percent of normal runoff.

FY Generation: The six main stem power plants generated 812 million kilowatt-hours (kWh) of electricity in September. Total energy production for 2013 was earlier forecasted to reach 8.0 billion kWh, but has been reduced to around 7.6 billion kWh. The long-term average is approximately 10 billion kWh.

Purchased Power: Purchased power is holding steady at low $20s for off-peak power and upper $30s for on-peak power.

Rocky Mountain Region

Drought conditions remain in some of the LAP area this year but are much improved over this time last year. The snowpack peaked later than normal and the peaks were 98 percent of average in the Bighorn Basin, 92 percent in the North Platte, and 110 percent in the Upper Colorado headwaters of the Colorado-Big Thompson Project (CBT). Low soil moisture and stream bank storage carrying over from last year and hot and dry conditions immediately after the snowpack peaked resulted in reservoir inflows less than what just the snowpack peaks would indicate. The resulting overall LAP reservoir storage at the end of September was below average with gains in the CBT and significant losses in the North Platte Basin since last September. The latest National Weather Service forecast indicates November through January temperatures will more likely be above average in Colorado with an equal chance of being above or below normal in Wyoming. The precipitation in that same period will more likely be above average in Wyoming with an equal chance of being above or below normal in Colorado.

LAP Water Conditions At-A-Glance Net At Plant LAP Generation (GWh)

Reservoir Storage Actual Reservoir Inflow FY2013 Actual Generation 1,000 acre-feet 1,000 acre-feet FY2014 Winter Projection end of % of annual % of % of September average average FY2013 average average average average

CBT 622.5 672.1 93% 738.2 787.3 94% Winter 12-13 512.8 724.0 71%

North Platte 773.8 1,246.2 62% 549.5 1,135.2 48% Summer 13 875.6 1,214.7 72%

Bighorn 1,915.4 1,988.1 96% 1,219.9 1,785.8 68% TOTAL FY13 1,388.4 1,938.7 72%

TOTAL 3,311.7 3,906.4 85% 2,507.6 3,708.3 68% Winter 13-14 470.8 724.0 65%

LAP generation was below average in FY2013 with the winter generation well below average. Extended scheduled unit outages required some plant bypass releases in the North Platte Basin over the winter. LAP generation was below average all summer with significant shortfalls in August and September due to the Grand Lake water clarity operation and then the historic flooding in Colorado. The Adams Tunnel import and associated CBT generation was curtailed for a six week period starting on June 23 as a means to improve the water clarity in Grand Lake. Flooding along Colorado’s Front Range in mid-September forced Reclamation to again curtail Adams Tunnel imports and CBT generation to avoid adding West Slope water to damaging flows in the Big Thompson River. No surplus firm generation was available for LAP customers at the regular LAP energy rate.

The upcoming winter season generation is expected to be about 65 percent of average and seasonal energy purchases have been arranged to support LAP firm electric service commitments. There continues to be an extended CBT outage due the September flooding. Reclamation has drained Lake Estes and will import little if any water through Adams Tunnel through November to allow for the removal of sediment and debris washed into the Lake by the flood. Heavier Adams Tunnel imports later in the winter will shift normal October and November CBT generation into February and March. There will also be minimum reservoir releases and associated generation in the North Platte Basin due to the deteriorating reservoir storage situation.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 15,272,000 acre feet, which is about 49 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (September 2013) were about 200 percent of average. Lake Powell elevation currently is about 3,591 feet, 109 feet from maximum reservoir level, and about 101 feet from the minimum generation level. The strong runoff in September 2013 boosted water year (WY) 2013 unregulated inflow to 5.12 MAF or 47 percent of average. That is six percent higher than was projected last month.

The hydrologic forecast for WY 2014 for Lake Powell, issued by the Colorado Basin River Forecast Center, projects that the most probable (median) unregulated inflow volume will be 9.65 MAF (89 percent of average based on the period 1981-2010). The Lake Powell operational tier for WY 2014 is the Mid-Elevation Release Tier with an annual release volume of 7.48 MAF.

Estimated SLCA/IP net generation for FY 2014 is 3,740 GWh as compared to 5,607 GWh based on the long-term historical average generation.

Estimated purchase power expenses for firming during the FY 2014 are about $48.2 million as compared to about $14.8 million based on long–term median historical releases. Purchase power availability in the region is abundant and prices are reasonable for this time of year. Firming purchases for the last month have been in the upper $30s on-peak and upper $20s to low $30s off-peak.

Desert Southwest Region

End of September Aggregate Storage (Mead, Mohave & Havasu): 14.546 MAF (14.629 MAF Aug 2013), 20.750 MAF (63-Year Historical Avg).

The Lake Mead end of September 2013 elevation was 1,106.92 ft. (0.79 ft. higher than end of Aug 2013 elevation ), or about 112.72 ft. below full storage elevation of 1,219.64 ft. and 56.92 ft. above the minimum generation elevation for Hoover of 1,050 ft.

Lake Mead’s elevation peaked at 1122.32 ft. in January of WY 2013 (11.86 ft. below the WY 2012 peak elevation of 1134.18 ft.), and dropped to a minimum elevation of 1105.92 ft. in July of WY 2013, a maximum fluctuation in lake elevation of 16.4 ft.

The Lake Powell operational tier for WY 2013 was the Upper Elevation Balancing Tier. Total releases from Lake Powell were 8.232 MAF for WY 2013 (actual of 9.47 MAF for WY 2012). The observed 2013 April-July unregulated inflow into Lake Powell was 2.56 MAF or 36 percent of average (actual of 2.06 MAF or 29 percent of average for 2012).

Basin Snow Pack and Precipitation: DSW hydrology is mostly dependent on the Colorado River Basin snow pack and precipitation above Lake Powell. The end of year WY 2013 precipitation was 91 percent of average.

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for Sept 2013 was 155 thousand acre-feet (KAF). The actual side inflow into Lake Mead for WY2013 was 824 KAF which represents a 12.9 percent increase over last year’s actual of 730 KAF, and represents 63.4 percent of the normal annual side inflow of 1.3 MAF.

Actual WY 2013 Generation: 5,082 GWh compared to 5,640 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2013 is 90 percent of the average historical generation.

Wholesale Power Market Conditions: The September market prices in the Desert Southwest averaged about $35/MWh firm on-peak, $27/MWh firm off-peak compared to $37/MWh firm on-peak, $26/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 4.368 MAF, compared to 6.130 MAF last year. WY 2013 ended with 1.738 MAF less storage than last water year. Accumulated inflow for the water year ended at 61 percent for Trinity, 72 percent for Shasta, 68 percent for Folsom and 55 percent for New Melones.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. WY 2013 started out with October recorded precipitation totaling 2.70 inches, which is below average for this month. November recorded precipitation totaled 13.00 inches, which is more than 200 percent of average. December came in at 17.10 inches, or 193 percent of average. January came in at 1.50 inches or 17 percent of its average. It ranks as one of the sixth driest. February ended at 0.90 inches or 11 percent of its average. March ended at only at 4.38 inches or 65 percent of its average. April ended at 1.52 inches or 41 percent of its average. May ended at 1.30 inches or 59 percent of its average. June ended at 1.80 inches or 186 percent of its average. July ended at zero inches. August ended at zero inches. September ended at 1.90 inches of recorded precipitation which is 239 percent of its monthly average. The cumulative total at this time is 46.20 inches or 92 percent of the total average of 50.30 inches.

The snowpack is assumed to reach its peak April 1. Therefore, snow water equivalents are reported as a percentage of this average. As of May 23, the North is at two percent, the Central is at two percent and the South is at one percent of this average. The Sacramento River Index forecast of water supply based upon May 1 conditions is “dry” (close to critical) for the 90 percent exceedence case and “dry” for the 50 percent case, reflecting the poor January, February and March, which has set records, but not in a good way. The State’s final yeartype declaration is based upon May 1 conditions at the 50 percent exceedence level. This year is officially “dry.”

Hydro Conditions and Purchase Power Monthly Outlook January 2014

Western Summary

• The most probable forecast of net generation for FY 2014 is 22,196 gigawatt-hours (GWh) or 82 percent of average. October through December generation was 71 percent of average. • The lower level forecast of generation for FY 2014 is 21,013 GWh or 77 percent of average. • The amount of power purchased for FY 2014 is expected to range between 4,274 and 4,659 GWh. • The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $46/MWh. This price compares to $45/MWh last year. • Purchase power expenses for FY 2014 are forecast to range between $196 and $210 million – compared to $182 million in FY 2013. • October through December purchases totaled $69 million – compared to $53 million for the same period last year.

Cumulative of Actual Purchase Power Expenses - FY 14 $225

$200 Most Probable/Actual $175 Dry

$150

$125

$100

$75

$50 Millionsof Dollars $25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month Upper Great Plains Region

Storage: December inflows totaled 162.5 MAF or 76 percent of average due to colder than normal temperatures. This inflow volume was a new record low for the month of December. The anticipated inflow for the April through July period is forecast to be 1,750.4 KAF or 101 percent of the 30 year average. Based upon the current water supply forecast, releases out of Canyon Ferry to the Missouri River below Holter Dam will be maintained near 3,100 cfs. Streamflows into Bighorn Lake during December were 92 percent of average. On January 1, the NRCS measured the snow water content of the mountain snowpack in the Bighorn Basin at 110 percent of average. Based on the January 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the April-July runoff into Bighorn Lake is expected to equal 1,143,200 acre-feet (107 percent of average).

As of January 21, 2014, the storage level at Canyon Ferry was 1,482,675 acre feet and the active conservation pool is 78.4 percent full. Storage at Yellowtail is 933,113 acre feet and the active conservation pool is 91.4 percent full.

COE: Colder weather throughout the system prevented the COE from reaching minimum winter release levels. Snowpack above Ft. Peck is above normal and has reached 107 percent while above Garrison it is 114 percent above normal. Runoff is now estimated to be 99 percent of normal. Forecast energy was raised to 7,508 GWh, up somewhat from last month. Average is 10,027 GWh.

Snow pack: The January 1 forecasted runoff for calendar year 2014 is 26.1 MAF. This runoff would be 110 percent of normal runoff.

FY Generation: The six main stem power plants generated 491 million kilowatt hours of electricity in December. Total energy production for 2013 was earlier forecasted to reach 8.0 billion kWh, but has been reduced to around 7.6 billion kWh. The long-term average is approximately 10 billion kWh.

Purchased Power: Extreme cold weather has caused the purchased power price to increase dramatically. Temperatures below zero and wind chills in dangerously high levels throughout the mid-section of the county caused gas prices to increase. Prices for power are in the upper thirties for off peak power and upwards of seventy dollars for on peak power. Addendum, during the last week in January, a pipeline was damaged which sent the price of natural gas skyrocketing, to the effect of seeing prices increase to $90 on-peak and $45 off-peak.

Rocky Mountain Region

Drought conditions remain in a few parts of the LAP area but LAP is now drought free on the whole and that is a significant improvement over last January. The snowpack was near or above average starting the month and remains so as of this writing. Heavy fall precipitation caused record reservoir inflows in some areas and the soil moisture and stream bank storage going into this winter is also an improvement over last year. The overall LAP reservoir storage at the end of December was still below average with gains in the Colorado-Big Thompson Project (CBT) and significant losses in the North Platte Basin since the end of last January. The latest National Weather Service forecast indicates February through April temperatures and precipitation will just as likely be above average as below average in Colorado and Wyoming.

LAP Water Conditions At-A-Glance

Reservoir Storage Snowpack Actual Reservoir Inflow To-Date 1,000 acre-feet inches snow water equivalent 1,000 acre-feet end of % of beginning of % of October % of December average average January average average - December average average

CBT 607.4 626.2 97% 84.3 84.0 100% 91.0 58.7 155%

North Platte 951.5 1,381.7 69% 155.8 130.8 119% 114.3 100.4 114%

Bighorn 2,020.7 1,822.0 111% 125.2 117.7 106% 282.4 201.2 140%

TOTAL 3,579.6 3,829.9 93% 365.3 332.5 110% 487.7 360.3 135%

Net At Plant Generation Projections (GWh)

Winter 13-14 520.8 718.0 73% 517.4 718.0 72% 535.4 718.0 75%

Summer 14 1,274.5 1,217.8 105% 963.6 1,217.8 79% 1,423.0 1,217.8 117%

TOTAL 2014 1,795.3 1,935.8 93% 1,481.0 1,935.8 77% 1,958.4 1,935.8 101%

LAP generation was below average in FY 2013 with the winter generation well below average. Extended scheduled unit outages required some plant bypass releases in the North Platte Basin last winter. LAP generation was below average all summer with significant shortfalls in August and September due to the Grand Lake water clarity operation and then the historic flooding in Colorado. The Adams Tunnel import and associated CBT generation was curtailed for a six week period starting on June 23 as a means to improve the water clarity in Grand Lake. Flooding along Colorado’s Front Range in mid-September forced Reclamation to again curtail Adams Tunnel imports and CBT generation to avoid adding West Slope water to damaging flows in the Big Thompson River. No surplus firm generation was available for LAP customers at the regular LAP energy rate.

The winter season generation is expected to be about 73 percent of average and seasonal energy purchases have been arranged to support LAP firm electric service commitments. There was an additional extended CBT outage due the flooding in September. Reclamation drained Lake Estes and curtailed all imports through Adams Tunnel through early December to allow for the removal of sediment and debris washed into the Lake by the flood. Imports resumed in mid-December and heavier Adams Tunnel imports later in the winter will shift normal October and November CBT generation into February and March. There will also be minimum reservoir releases and associated generation in the North Platte Basin due to depleted reservoir storage.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 14,494,000 acre feet, which is about 47 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (December, 2013) were about 84 percent of average. Lake Powell elevation currently is about 3,582 feet, 118 feet from maximum reservoir level, and about 92 feet from the minimum generation level.

The forecast for the 2014 April to July water supply season for Lake Powell, issued by the Colorado Basin River Forecast Center, projects that the most probable (median) unregulated inflow volume will be 6.81 MAF (95 percent of average based on the period 1981-2010). The water year 2014 forecast increased by 560 KAF since last month. The winter snow accumulation season has started off near average (currently 96 percent of median); however, at this early point in the season, there is still significant uncertainty regarding the final snowpack and resulting runoff.

The April-July forecast ranges from a minimum probable of 4.0 MAF (56 percent of average) to a maximum probable of 10.2 MAF (142 percent of average). For reference, the 30-year April-July average is 7.16 MAF. There is a 10 percent chance that inflows could be higher than the maximum probable and a 10 percent chance they could be lower than the minimum probable. The Lake Powell operational tier for water year 2014 is the Mid-Elevation Release Tier with an annual release volume of 7.48 MAF.

Based on that inflow forecast, estimated SLCA/IP net generation for Fiscal Year 2014 is 3,784 GWh as compared to 5,584 GWh based on the long-term historical average generation.

Estimated purchase power expenses for firming during the fiscal year 2014 are about $54.9 million as compared to about $17.7 million based on long-term median historical releases. Purchase power availability in the region is abundant and prices are reasonable for this time of year. Firming purchases for the last month have been in the upper $30’s on-peak and low $30’s off-peak, but have spiked for short periods during extreme weather events.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 14.481 MAF (14.434 MAF Nov-2013), 20.818 MAF (73-Year Historical Avg).

The Lake Mead end of December 2013 elevation was 1,106.73 feet (.37 feet higher than end of Nov 2013 elevation ), or about 112.91 feet below full storage elevation of 1,219.64 feet and 56.73 feet above the minimum generation elevation for Hoover of 1,050 feet.

Lake Mead’s elevation is projected to peak at 1109.31 ft in January of WY 2014 (13.01 feet below the WY 2013 peak elevation of 1122.32 feet), and drop to a minimum elevation of 1084.71 feet in September of WY 2014, a maximum fluctuation in lake elevation of 24.6 feet

The Lake Powell operational tier for WY 2014 is currently the Mid-Elevation Release Tier. Total releases from Lake Powell are projected to average about 7.48 MAF for WY 2014 (actual of 8.232 MAF for WY 2013). The projected 2014 April – July unregulated inflow into Lake Powell is 6.81 MAF or 95 percent of average (actual of 2.56 MAF or 36 percent of average for 2013).

Basin Snow Pack and Precipitation: DSW hydrology, or the Lower Colorado River Basin, is mostly dependent on the Colorado River Basin snow pack and precipitation above Lake Powell. The WY 2014 precipitation is currently 92 percent of average and the snowpack is 96 percent of the 30-year (1981-2010) median.

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for December 2013 was 41 KAF. The projected side inflow into Lake Mead for WY2014 is 866 KAF which represents a 5 percent increase over last year’s actual of 824 KAF, and represents 67 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2014 Generation: 5,268 GWh compared to 5,634 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2014 is 94 percent of the average historical generation.

Wholesale Power Market Conditions: The December market prices in the Desert Southwest averaged about $43/MWh firm on-peak, $40/MWh firm off-peak compared to $33/MWh firm on- peak, $26/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 4.04 million-acre-feet, compared to 7.527 MAF last year. Accumulated inflow for the water year-to-date is 13 percent of the 15-year average for Trinity, 43 percent for Shasta, 21 percent for Folsom and 52 percent for New Melones. None of the reservoirs is in flood control operations at this time.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. This water year started out with October recorded precipitation totaling 0.72 inches, which is 23 percent of the monthly average. November recorded precipitation totaled 1.66 inches, which is 26 percent of average. December came in at 0.92 inches, or 10 percent of average. January is looking very dry though there is some precipitation in the forecast. As of January 24, January is at 0.22 inches or 2 percent of its average. The cumulative total at this time is 3.52 inches or 7 percent of the annual. December and January are the months with the highest average, with February very close. At the writing of this report, Sacramento has just ended 53 days without precipitation.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak April 1. Therefore, snow water equivalents are reported as a percentage of this average. As of January 24, the North is at 4 percent, the Central is at 8 percent and the South is at 8 percent of this average. The Sacramento River Index forecast of water supply based upon January 1 conditions is “critical” for the 90 percent exceedence as well as the 50 percent case. Calendar Year 2013 has been called the driest on record. Water Year 2014 would appear to be following suit.

The average projection of net generation is again taken from the latest modeling using the update to our customers’ “Green Book.” This average, at 3.34 GWh, is less than the 3.63 GWh from the CVPIA PEIS planning studies. Under the Post 2004 Marketing Plan, net generation, after Project Use load, First Preference Customer load and sub-control area reserve requirement, becomes the Base Resource which is allocated among the Base Resource, Variable Resource and Full Load Service Customers. This past fiscal year ended at approximately 91 percent of that average. Reclamation forecasts are based upon December 1 conditions, which were based upon water supply forecast of “critical” for the 90 percent exceedence and “dry” for the 50 percent exceedence. These forecasts would be 70 percent and 72 percent of this “Green Book” average net generation. Delta salinity has caused export pumping to be extremely low even while reservoir releases have increased. Hydro Conditions and Purchase Power Monthly Outlook February 2014

Western Summary

• The most probable forecast of net generation for FY 2014 is 22,266 gigawatt-hours (GWh) or 82 percent of average. October through January generation was 73 percent of average. • The lower level forecast of generation for FY 2014 is 21,257 GWh or 73 percent of average. • The amount of power purchased for FY 2014 is expected to range between 4,214 and 4,505 GWh. • The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $48/megawatt-hours (MWh). This price compares to $45/MWh last year. • Purchase power expenses for FY 2014 are forecast to range between $201 and $213 million – compared to $182 million in FY 2013. • The most probable forecast of October through January purchase power expenses is $99 million1 – compared to $74 million for the same period last year.

Cumulative of Actual Purchase Power Expenses - FY 14 $225

$200 Most Probable/Actual $175 Dry

$150

$125

$100

$75

$50 Millionsof Dollars $25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month

1 At this time, actual Western-wide purchase power expenses are not available for January due to the lack of certain Western Regional data. Upper Great Plains Region

Storage: The anticipated inflow for the April through July period is forecast to be 1,570.5 thousand acre-feet (kAF) or 91 percent of the 30 year average. Based upon the current water supply forecast, releases out of Canyon Ferry to the Missouri River below Holter Dam will be maintained near 3,100 cubic feet per second. Streamflows into Bighorn Lake during January were 92 percent of average. On February 1, the NRCS measured the snow water content of the mountain snowpack in the Bighorn Basin at 109 percent of average. Based on the February 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the April-July runoff into Bighorn Lake is expected to equal 1,140,000 acre-feet (107 percent of average).

As of February 20, 2014, the storage level at Canyon Ferry was 1,453,782 acre-feet and the active conservation pool is 78.8 percent full. Storage at Yellowtail is 890,663 acre-feet and the active conservation pool is 87.3 percent full.

COE: Continued cold weather throughout the system prevented the COE from decreasing Gavins Point releases to minimum so far this winter. Ice formation has caused lower levels at reaches near Sioux City. Lower levels have increased generation throughout the system for the month of February. The reaches below Oahe have also experienced icing causing a damming effect that increases water levels. Reaches around Bismarck are frozen over and remain that way. Runoff is now estimated to be 106 percent of normal. Forecast energy was raised to 8,404 GWh, up somewhat from last month. The average is 10,027 GWh.

Snow pack: The January 1 forecasted runoff for calendar year 2014 is 26.1 million acre-feet (MAF). This runoff would be 104 percent of normal runoff.

FY Generation: The six main stem power plants generated 564 million kilowatt-hours (kWh) of electricity in January. Total energy production for 2014 is forecasted to be 8,404 GWH, up from 7,564 forecasted in December. The long-term average is approximately 10 billion kWh.

Purchased Power: The extreme cold weather experienced lately has somewhat abated and prices have come back to normal. With the COE releases being down, purchased power is the rule of thumb with prices dropping back to normal winter prices.

Rocky Mountain Region

The LAP area is essentially drought free. The overall LAP reservoir storage at the end of February was below average with gains in the Colorado-Big Thompson Project (CBT) and significant losses in the North Platte Basin since the end of last February. The snowpack was above average starting the month and remains so as of this writing. The spring snow melt runoff is forecast to be above average for the CBT and Bighorn Basin and below average for the North Platte Basin. The latest National Weather Service forecast indicates March through May temperatures and precipitation will just as likely be above average as below average in Northern Colorado and Wyoming.

LAP Water Conditions At-A-Glance

Reservoir Storage Snowpack Most Probable Reservoir Inflow 1,000 acre-feet inches snow water equivalent 1,000 acre-feet (April - July) end of % of beginning of % of February % of January average average February average average forecast average average

CBT 597.4 616.1 97% 283.2 229.7 123% 668.0 588.0 114%

North Platte 992.6 1,419.0 70% 264.0 231.7 114% 700.0 750.0 93%

Bighorn 1,972.6 1,769.8 111% 250.7 226.1 111% 1,432.6 1,318.4 109%

TOTAL 3,562.6 3,804.9 94% 797.9 687.5 116% 2,800.6 2,656.4 105%

Net At Plant Generation Projections (GWh)

Winter 13-14 521.8 718.0 73% 521.3 718.0 73% 548.4 718.0 76%

Summer 14 1,288.6 1,217.8 106% 999.4 1,217.8 82% 1,483.6 1,217.8 122%

TOTAL 2014 1,810.4 1,935.8 94% 1,520.7 1,935.8 79% 2,032.0 1,935.8 105%

The upcoming summer season generation is expected to fall between 80 percent and 120 percent of average and, as of now, there is no curtailment of Adams Tunnel imports and associated CBT generation planned for late summer as a means to improve water clarity in Grand Lake.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 14,071,000 acre-feet, which is about 45 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (January, 2014) were about 78 percent of average. Lake Powell elevation currently is about 3,577 feet, 123 feet from maximum reservoir level, and about 87 feet from the minimum generation level.

The forecast for the 2014 April to July water supply season for Lake Powell, issued on Feb 4th by the Colorado Basin River Forecast Center, projects that the most probable (median) unregulated inflow volume will be 7.25 MAF (101 percent of average based on the period 1981-2010). The April-July forecast increased by 440 kAF since last month. The winter snow accumulation season has tracked near average so far (currently 111 percent of median), however we are currently roughly two-thirds of the way through the snow accumulation season and there is still uncertainty regarding the final snowpack and resulting runoff. The April-July forecast ranges from a minimum probable of 4.75 MAF (66 percent of average) to a maximum probable of 10.3 MAF (144 percent of average).

Based on that inflow forecast, estimated SLCA/IP net generation for Fiscal Year 2014 is 3,895 GWh as compared to 5,584 GWh based on the long-term historical average generation.

Estimated purchase power expenses for firming during the fiscal year 2014 are about $59.3 million as compared to about $17.7 million based on long–term median historical releases. Purchase power availability in the region is good and prices are somewhat higher than usual for this time of year. Firming purchases for the last month have been averaging in the upper $30’s on-peak and low $30’s off-peak, but have spiked higher during extreme cold weather events.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 14.721 MAF (14.481 MAF Dec-2013), 20.960 MAF (64-Year Historical Avg).

The Lake Mead end of January 2014 elevation was 1,108.75 ft. (2.02 ft. higher than end of Dec 2013 elevation ), or about 110.89 ft. below full storage elevation of 1,219.64 ft. and 58.75 ft. above the minimum generation elevation for Hoover of 1,050 ft.

Lake Mead’s elevation is projected to peak at 1108.75 ft in January of WY 2014 (13.57 ft. below the WY 2013 peak elevation of 1122.32 ft.), and drop to a minimum elevation of 1083.74 ft. in September of WY 2014, a maximum fluctuation in lake elevation of 25.01 ft.

The Lake Powell operational tier for WY 2014 is currently the Mid-Elevation Release Tier. Total releases from Lake Powell are projected to average about 7.48 MAF for WY 2014 (actual of 8.232 MAF for WY 2013). The projected 2014 April – July unregulated inflow into Lake Powell is 7.25 MAF or 101 percent of average (actual of 2.56 MAF or 36 percent of average for 2013).

Basin Snow Pack and Precipitation: DSW hydrology, or the Lower Colorado River Basin, is mostly dependent on the Colorado River Basin snow pack and precipitation above Lake Powell. The WY 2014 precipitation is currently 103 percent of average and the snowpack is 112 percent of the 30- year (1981-2010) median.

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for January 2014 was 44 kAF. The projected side inflow into Lake Mead for WY2014 is 831 kAF which represents a 1 percent increase over last year’s actual of 824 kAF, and represents 64 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2014 Generation: 5343 GWh compared to 5638 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2014 is 95 percent of the average historical generation.

Wholesale Power Market Conditions: The January market prices in the Desert Southwest averaged about $40/MWh firm on-peak, $34/MWh firm off-peak compared to $43/MWh firm on-peak, $40/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 4.263 MAF, compared to 7.742 MAF last year. Accumulated inflow for the water year-to-date is 19 percent of the 15-year average for Trinity, 42 percent for Shasta, 36 percent for Folsom and 50 percent for New Melones. None of the reservoirs is in flood control operations at this time.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. October recorded precipitation totaled 0.72 inches, or 23 percent of the monthly average. November recorded precipitation totaled 1.66 inches, or 26 percent of average. December came in at 0.92 inches, or 10 percent of average. January came in at 1.20 inches or 13 percent of its average. As of the 26th, February is at 8.40 inches or 102 percent of its average. It started raining and snowing again with storms expected throughout the weekend. The cumulative total at this time is 12.90 inches or 26 percent of the annual average. December and January are the months with the highest average, with February very close. Many are hoping for a “miracle March,” since it has the next highest average precipitation of the water year.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak April 1. Therefore, snow water equivalents are reported as a percentage of this average. As of February 26, the North is at 10 percent, the Central is at 25 percent and the South is at 17 percent of this average. The Sacramento River Index forecast of water supply based upon February 1 conditions is “critical” for the 90 percent exceedence as well as the 50 percent case. Recent gains in precipitation will be reflected in the March 1 conditions forecasts.

The average projection of net generation is again taken from the latest modeling using the update to our customers’ “Green Book.” This average, at 3.34 GWh, is less than the 3.63 GWh from the CVPIA PEIS planning studies. Under the Post 2004 Marketing Plan, net generation, after Project Use load, First Preference Customer load and sub-control area reserve requirement, becomes the Base Resource which is allocated among the Base Resource, Variable Resource and Full Load Service Customers. This past fiscal year ended at approximately 91 percent of that average. Reclamation forecasts are based upon December 1 conditions, which were based upon water supply forecast of “critical” for the 90 percent exceedence and “dry” for the 50 percent exceedence. These forecasts would be 67 percent and 68 percent of this “Green Book” average net generation. Currently, Delta export pumping increases to take advantage of precipitation runoff, but drops down again as soon as Delta salinity again becomes a concern once storms have passed. Hydro Conditions and Purchase Power Monthly Outlook March 2014

Western Summary

• The most probable forecast of net generation for fiscal year (FY) 2014 is 23,039 gigawatt- hours (GWh) or 85 percent of average. October through February generation was 73 percent of average. • The lower level forecast of generation for FY 2014 is 21,824 GWh or 80 percent of average. • The amount of power purchased for FY 2014 is expected to range between 4,050 and 4,484 GWh. • The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $49/megawatt-hour (MWh). This price compares to $42/MWh last year. • Purchase power expenses for FY 2014 are forecast to range between $198 and $230 million – compared to $182 million in FY 2013. • October through February purchases totaled $142 million – compared to $92 million for the same period last year.

Cumulative of Actual Purchase Power Expenses - FY 14 $250

$225 Most Probable/Actual $200 Dry

$175

$150

$125

$100

$75

$50 Millionsof Dollars

$25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month Upper Great Plains Region

Storage: The anticipated inflow for the April through July period is forecast to be 2,027.7 thousand acre-feet (kAF) or 117 percent of the 30 year average. Based upon the current water supply forecast, releases out of Canyon Ferry to the Missouri River below Holter Dam is expected to be maintained near or above 4,100 cubic feet per second beginning in late March and continue through the remainder of the year. Streamflows into Bighorn Lake during February were 96 percent of average. On March 1, the NRCS measured the snow water content of the mountain snowpack in the Bighorn Basin at 128 percent of average. Based on the March 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the April-July runoff into Bighorn Lake is expected to equal 1,646,700 acre-feet (154 percent of average).

As of March 21, 2014, the storage level at Canyon Ferry was 1,460,387 acre-feet and the active conservation pool is 77.2 percent full. Storage at Yellowtail is 888,152 acre-feet and the active conservation pool is 87.0 percent full.

COE: As of March 7, mountain snowpack is about 125 percent. There is not much plains snow in the eastern Dakotas. Runoff forecast was increased to 30.6 million acre-feet (MAF), which is about 20 percent above normal. Total water volume stored in the Missouri Mainstream Reservoir is about 50.6 MAF, even though storage is down due to the lingering drought. Runoff is now estimated to be 106 percent of normal. Forecast energy was raised to 8,404 GWh, up somewhat from last month. The average is 10,027 GWh.

Snow pack: March 1 forecasted runoff for calendar year 2014 is 30.6 MAF. This runoff would be 121 percent of normal runoff.

FY Generation: The six main stem power plants generated 499 million kilowatt hours of electricity in February. Total energy production for 2014 is forecasted to be 8,404 GWh, up from 7,564 GWh forecasted in December. The long-term average is approximately 10 billion kWh.

Purchased Power: The extreme cold weather has abated and so the price of power is starting to come back down. Prices for off peak power range from $24-$28 and on peak power ranges up to the mid-$40s.

Rocky Mountain Region

The LAP area is essentially drought free. The overall LAP reservoir storage at the end of February was below average with gains in the Colorado-Big Thompson Project (CBT) and significant losses in the North Platte Basin since the end of last February. The snowpack was well above average starting the month and remains so as of this writing. The spring snow melt runoff is forecast to be above average for the North Platte Basin and well above average for the CBT and Bighorn Basin. The latest National Weather Service forecast indicates April through June temperatures and precipitation will just as likely be above average as below average in Northern Colorado and Wyoming.

LAP Water Conditions At-A-Glance

Reservoir Storage Snowpack Most Probable Reservoir Inflow 1,000 acre-feet inches snow water equivalent 1,000 acre-feet (April - July) end of % of beginning of % of March % of February average average March average average forecast average average

CBT 587.4 607.3 97% 335.7 248.0 135% 783.0 588.0 133%

North Platte 1,032.4 1,456.3 71% 319.9 265.0 121% 800.0 770.0 104%

Bighorn 1,937.3 1,730.4 112% 383.9 278.9 138% 1,947.0 1,318.4 148%

TOTAL 3,557.1 3,794.0 94% 1,039.5 791.9 131% 3,530.0 2,676.4 132%

Net At Plant Generation Projections (GWh)

Winter 13-14 532.4 718.0 74% 526.0 718.0 73% 537.5 718.0 75%

Summer 14 1,346.7 1,217.8 111% 1,111.9 1,217.8 91% 1,588.3 1,217.8 130%

TOTAL 2014 1,879.1 1,935.8 97% 1,637.9 1,935.8 85% 2,125.8 1,935.8 110%

The winter season generation is expected to be about 75 percent of average. There was an extended CBT outage due the flooding in September. Reclamation drained Lake Estes and curtailed all imports through Adams Tunnel through early December to allow for the removal of sediment and debris washed into the Lake by the flood. Imports resumed in mid-December and heavier Adams Tunnel imports later in the winter shifted normal October and November CBT generation into February and March. There have been minimum reservoir releases and associated generation in the North Platte Basin due to depleted reservoir storage.

The upcoming summer season generation is expected to fall between 90 percent and 130 percent of average. If heavy runoff and reduced water demands result in nearly full East Slope storage while the possibly of a late summer spill of Lake Granby is low then conditions would be right for another curtailment of Adams Tunnel imports and associated CBT generation in the late summer as a means to improve water clarity in Grand Lake.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 13,947,000 acre-feet, which is about 45 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (February 2014) were about 87 percent of average. Lake Powell elevation currently is about 3,575 feet, 125 feet from maximum reservoir level, and about 85 feet from the minimum generation level. Lake Powell elevation is expected to increase beginning in April as spring runoff begins entering the reservoir.

The forecast for the 2014 April to July water supply season for Lake Powell, issued on March 4, 2014, by the Colorado Basin River Forecast Center, projects that the most probable (median) unregulated inflow volume will be 8.30 MAF (116 percent of average based on the period 1981- 2010). The April-July forecast increased by 1.05 MAF since last month. The winter snow accumulation season has tracked near average to slightly above average in the past month (currently 115 percent of median). There is currently about one more month remaining for the typical snow accumulation season so there is still uncertainty regarding the final snowpack and resulting runoff. The April-July forecast ranges from a minimum probable of 6.00 MAF (84 percent of average) to a maximum probable of 11.1 MAF (155 percent of average). For reference, the 30-year April-July average is 7.16 MAF. There is a 10 percent chance that inflows could be higher than the maximum probable, and a 10 percent chance they could be lower than the minimum probable.

Based on that inflow forecast, estimated SLCA/IP net generation for FY 2014 is 4,141 GWh as compared to 5,584 GWh based on the long-term historical average generation.

Estimated purchase power expenses for firming during the FY 2014 are about $51.8 million, as compared to about $18.4 million based on long–term median historical releases. Purchase power availability in the region is good and prices are somewhat higher than usual for this time of year, but are coming down as the weather warms. Firming purchases for the last month have been averaging in the low $40’s on-peak and low $30’s off-peak, but have spiked higher during extreme cold weather events.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 14.708 MAF (14.721 MAF Jan-2014), 20.960 MAF (64-Year Historical Avg).

The Lake Mead end of February 2014 elevation was 1,107.94 feet (0.81 feet lower than end of Jan 2014 elevation ), or about 111.7 feet below full storage elevation of 1,219.64 feet and 57.94 feet above the minimum generation elevation for Hoover of 1,050 feet.

Lake Mead’s elevation peaked at 1,108.75 feet in January of WY 2014 (13.57 feet below the WY 2013 peak elevation of 1,122.32 feet), and is projected to drop to a minimum elevation of 1,082.77 feet in September of WY 2014, a maximum fluctuation in lake elevation of 25.98 feet.

The Lake Powell operational tier for WY 2014 is currently the Mid-Elevation Release Tier. Total releases from Lake Powell are projected to average about 7.48 MAF for WY 2014 (actual of 8.232 MAF for WY 2013). The projected 2014 April - July unregulated inflow into Lake Powell (as of March 17, 2014) is 8.0 MAF or 112 percent of average (actual of 2.56 MAF or 36 percent of average for 2013).

Basin Snow Pack and Precipitation: DSW hydrology, or the Lower Colorado River Basin, is mostly dependent on the Colorado River Basin snow pack and precipitation above Lake Powell. The WY 2014 precipitation is currently 101 percent of average and the snowpack is 111 percent of the 30- year (1981-2010) median.

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for February 2014 was 76 kAF. The projected side inflow into Lake Mead for WY 2014 is 823 kAF which represents a 0.12 percent decrease over last year’s actual of 824 kAF, and represents 63 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2014 Generation: 5,363 GWh compared to 5,638 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2014 is 95 percent of the average historical generation.

Wholesale Power Market Conditions: The January market prices in the Desert Southwest averaged about $60/MWh firm on-peak, $48/MWh firm off-peak compared to $40/MWh firm on-peak, $34/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 4.835 MAF, compared to 7.920 MAF last year. Accumulated inflow for the water year-to-date is 39 percent of the 15-year average for Trinity, 48 percent for Shasta, 40 percent for Folsom and 46 percent for New Melones. None of the reservoirs is in flood control operations at this time.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. October recorded precipitation totaled 0.72 inches, or 23 percent of the monthly average. November recorded precipitation totaled 1.66 inches, or 26 percent of average. December came in at 0.92 inches, or 10 percent of average. January came in at 1.20 inches or 13 percent of its average. February ended at 14.20 inches or 130 percent of its average. The cumulative total at this time is 20.94 inches or 41 percent of the annual average. December and January are the months with the highest average, with February very close. March is next, but has been dry until just recently. As of the 24th, March is at 5.74 inches or 86 percent of its average. It started raining and snowing again with storms expected throughout the weekend.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak April 1. Therefore, snow water equivalents are reported as a percentage of this average. As of February 26, the North is at 10 percent, the Central is at 25 percent and the South is at 17 percent of this average. The Sacramento River Index forecast of water supply, based upon March 1 conditions forecast, remains “critical” for the 90 percent exceedence as well as the 50 percent case. Recent gains in precipitation will be reflected in the April 1 conditions forecasts. The year type declaration will be based upon May 1 conditions at the 50 percent exceedence level.

The average projection of net generation is again taken from the latest modeling using the update to our customers’ “Green Book.” This average, at 3.34 GWh, is less than the 3.63 GWh from the CVPIA PEIS planning studies. Under the Post-2004 Marketing Plan, net generation, after Project Use load, First Preference Customer load and sub-control area reserve requirement, becomes the Base Resource which is allocated among the Base Resource, Variable Resource and Full Load Service Customers. This past FY ended at approximately 91 percent of that average. Reclamation forecasts are based upon January 1 conditions, which were based upon water supply forecast of “critical” for the 90 percent exceedence and “critical” for the 50 percent exceedence. These forecasts would be 65 percent and 66 percent of this “Green Book” average net generation. Currently, Delta export remains low because the initial storm system did not produce as much as predicted. Hydro Conditions and Purchase Power Monthly Outlook April 2014

Western Summary

• The most probable forecast of net generation for fiscal year (FY) 2014 is 23,814 gigawatt- hours (GWh) or 88 percent of average. October through March generation was 77 percent of average. • The lower level forecast of generation for FY 2014 is 22,608 GWh or 83 percent of average. • The purchased power for FY 2014 is expected to range between 3,469 and 3,871 GWh. • The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $57/megawatt-hour (MWh). This price compares to $41/MWh last year. • Purchase power expenses for FY 2014 are forecast to range between $199 and $215 million. • The most probable forecast of October through March purchase power expenses is $162 million1 – compared to $117 million for the same period last year.

1 At this time, the actual total of Western-wide purchase power expenses is not available for March due to the lack of certain Western Regional data. Upper Great Plains Region

Storage: The NRCS’s snowpack conditions have increased to 136 percent of the 30 year median; therefore, the anticipated inflow for the April through July period is forecast to be 2457.1 thousand acre-feet (kAF) or 142 percent of the 30 year average. Streamflows into Bighorn Lake during March were 144 percent of average. On April 1, the NRCS measured the snow water content of the mountain snowpack in the Bighorn Basin at 134 percent of average. Based on the April 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the April-July runoff into Bighorn Lake is expected to equal 1,960,800 acre-feet (194 percent of average).

As of April 18, 2014, the storage level at Canyon Ferry was 1,352,441 acre-feet and the active conservation pool is 71.5 percent full. Storage at Yellowtail is 767,236 acre-feet and the active conservation pool is 75.2 percent full.

COE: As of April 11, 2014, mountain snowpack above Ft. Peck is about 128 percent of normal. Between Ft. Peck and Garrison the snowpack is 137 percent. Currently the system storage is slightly below normal due to drought in 2012 but the greater than average snowpack will bring system storage to normal levels and also increase system generation to near normal for the year. Runoff is now estimated to be 106 percent of normal. Forecast energy was raised to 8,404 GWh, up somewhat from last month. The average is 10,027 GWh.

Snow pack: April 1 forecasted runoff for calendar year 2014 is 32.0 million acre-feet (MAF). This runoff would be 127 percent of normal runoff.

FY Generation: The six main stem power plants generated 619 million kilowatt hours of electricity in March. Total energy production for 2014 is forecasted to be 9,640 GWh, up from 8,929 GWh forecasted in March. The long-term average is approximately 10 billion kWh.

Purchased Power: The extreme cold weather has abated and so the price of power is starting to come back down. Prices for off peak power range from lower to mid 20s and on peak power ranges up to mid thirties.

Rocky Mountain Region

The LAP area is drought free. The reservoir inflow was above average in the Colorado River headwaters and Bighorn Basin over the winter and was average in the North Platte Basin. The overall LAP reservoir storage at the end of March was below average with gains in the Colorado- Big Thompson Project (CBT) and losses in the North Platte Basin since the end of last March. The snowpack was well above average starting the month and remains so as of this writing. The latest National Weather Service forecast indicates May through July temperatures will just as likely be above average as below average in Northern Colorado and Wyoming. The precipitation is more likely to be above average in Colorado and just as likely be above average as below average in Wyoming. The spring snow melt runoff is now forecast to be well above average for all three basins.

LAP Water Conditions At-A-Glance

Reservoir Storage Snowpack Most Probable Reservoir Inflow 1,000 acre-feet inches snow water equivalent 1,000 acre-feet (April - July) end of % of beginning of % of April % of March average average April average average forecast average average

CBT 574.1 599.1 96% 489.2 361.6 135% 867.0 588.0 147%

North Platte 1,109.3 1,507.8 74% 474.1 375.9 126% 950.0 770.0 123%

Bighorn 1,878.0 1,719.9 109% 491.1 353.8 139% 2,265.9 1,315.0 172%

TOTAL 3,561.4 3,826.8 93% 1,454.4 1,091.3 133% 4,082.9 2,673.0 153%

Net At Plant Generation Projections (GWh)

Winter 13-14 555.3 718.0 77% 555.3 718.0 77% 555.3 718.0 77%

Summer 14 1,436.5 1,217.8 118% 1,319.1 1,217.8 108% 1,613.2 1,217.8 132%

TOTAL 2014 1,991.8 1,935.8 103% 1,874.4 1,935.8 97% 2,168.5 1,935.8 112%

The winter season generation was 77 percent of average. There was an extended CBT outage due the flooding in September. Reclamation drained Lake Estes and curtailed all imports through Adams Tunnel through early December to allow for the removal of sediment and debris washed into the Lake by the flood. Imports resumed in mid-December and heavier Adams Tunnel imports later in the winter shifted normal October and November CBT generation into February and March. There were minimum winter reservoir releases and associated generation in the North Platte Basin due to depleted reservoir storage.

The upcoming summer season generation is expected to fall between 108 percent and 132 percent of average. Heavy runoff and likely reduced water demand will result in nearly full East Slope storage. If the possibility of a late summer spill of Lake Granby is low then conditions would be right for another curtailment of Adams Tunnel imports and associated CBT generation in the late summer as a means to improve water clarity in Grand Lake.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 13,919,000 acre-feet, which is about 45 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (March 2014) were about 77 percent of average. Lake Powell elevation currently is about 3,574 feet, 126 feet from maximum reservoir level and about 84 feet from the minimum generation level. Lake Powell elevation is expected to increase in April as spring runoff begins entering the reservoir. Based on the current forecast, the 24-Month study for April projects Lake Powell elevation will peak near approximately 3,614 feet near the end of June and end the water year near 3,610 feet with approximately 12.71 MAF in storage (52 percent capacity).

The forecast for the 2014 April to July water supply season for Lake Powell, issued on April 2, 2014, by the Colorado Basin River Forecast Center, projects that the most probable (median) unregulated inflow volume will be 7.85 MAF (110 percent of average based on the period 1981- 2010). The April-July forecast decreased by 0.45 MAF since last month. The winter snow accumulation season has tracked slightly above average over the past month (currently 112 percent of median). We are nearing the end of the typical snow accumulation season and spring runoff is expected to begin in many sub-basins over the next month. However, the timing and final volume of spring runoff is still uncertain. The April-July forecast ranges from a minimum probable of 5.80 MAF (81 percent of average) to a maximum probable of 10.3 MAF (144 percent of average). For reference, the 30-year April-July average is 7.16 MAF. There is a 10 percent chance that inflows could be higher than the maximum probable and a 10 percent chance they could be lower than the minimum probable.

Based on that inflow forecast, estimated SLCA/IP net generation for FY 2014 is 4,133 GWh as compared to 5,584 GWh based on the long-term historical average generation.

Estimated purchase power expenses for firming during FY 2014 are about $51.9 million as compared to about $18.4 million based on long–term median historical releases. Purchase power availability in the region is good and prices are somewhat higher than usual for this time of year. Firming purchases for the last month have been averaging about $40 on-peak and low $35 off-peak.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 14.111 MAF (14.708 MAF as of February 2014), with 20.788 MAF being the 64-year historical average.

The Lake Mead end of March 2014 elevation was 1,101.71 feet (6.23 feet lower than end of February 2014 elevation), or about 117.9 feet below full storage elevation of 1,219.64 feet and 51.71 feet above the minimum generation elevation for Hoover of 1,050 feet.

Lake Mead’s elevation peaked at 1108.75 feet in January of water year (WY) 2014 (13.57 feet below the WY 2013 peak elevation of 1122.32 feet), and is projected to drop to a minimum elevation of 1081.97 feet in September of WY 2014, a maximum fluctuation in lake elevation of 26.78 feet.

The Lake Powell operational tier for WY 2014 is currently the Mid-Elevation Release Tier. Total releases from Lake Powell are projected to average about 7.48 MAF for WY 2014 (actual of 8.232 MAF for WY 2013). The projected 2014 April – July unregulated inflow into Lake Powell (as of 4/8/14) is 7.85 MAF or 110 percent of average (actual of 2.56 MAF or 36 percent of average for 2013).

Basin Snow Pack and Precipitation: DSW hydrology, or the Lower Colorado River Basin, is mostly dependent on the Colorado River Basin snow pack and precipitation above Lake Powell. The WY 2014 precipitation is currently 98 percent of average and the snowpack is 100 percent of the 30-year (1981-2010) median.

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for March 2014 was 33 kAF. The projected side inflow into Lake Mead for WY2014 is 788 kAF which represents a 4.4 percent decrease over last year’s actual of 824 kAF, and represents 61 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2014 Generation: 5,342 GWh compared to the 5,639 GWh historical average. The projected Hoover and Parker-Davis generation for WY 2014 is 95 percent of the average historical generation.

Wholesale Power Market Conditions: The March market prices in the Desert Southwest averaged about $42/MWh firm on-peak, $33/MWh firm off-peak compared to $60/MWh firm on-peak, $48/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 5.195 MAF, compared to 8.201 MAF last year. Accumulated inflow for the water year-to-date is 41 percent of the 15-year average for Trinity, 51 percent for Shasta, 42 percent for Folsom, and 43 percent for New Melones. None of the reservoirs is in flood control operations at this time.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. October recorded precipitation totaled 0.72 inches, or 23 percent of the monthly average. November recorded precipitation totaled 1.66 inches, or 26 percent of average. December came in at 0.92 inches, or 10 percent of average. January came in at 1.20 inches or 13 percent of its average. February ended at 14.20 inches or 130 percent of its average. March came in at 10.21 inches, or 153 percent of average. The cumulative total at this time is 26.91 inches or 53 percent of the annual average. December and January are the months with the highest average, with February very close. March is next and we received another 5 inches during the last week of that month, but April has been rather dry thus far with only 1.50 inches of measurable precipitation.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak on April 1. Therefore, snow water equivalents are reported as a percentage of this average. As of April 24, the North is at 7 percent, the Central is at 20 percent, and the South is at 15 percent of this average. The Sacramento River Index forecast of water supply, based upon April 1 conditions forecast, remains “critical” for the 90 percent exceedence as well as the 50 percent case. Still, March gains in precipitation are reflected in the April 1 conditions forecasts. The year type declaration will be based upon May 1 conditions at the 50 percent exceedence level.

Hydro Conditions and Purchase Power Monthly Outlook May 2014

Western Summary

 The most probable forecast of net generation for fiscal year (FY) 2014 is 23,766 gigawatt- hours (GWh) or 87 percent of average. October through April generation was 81 percent of average.  The lower level forecast of generation for FY 2014 is 22,809 GWh or 84 percent of average.  The purchased power for FY 2014 is expected to range between 4,198 and 4,548 GWh.  The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $50/megawatt-hour (MWh). This price compares to $43/MWh last year.  Purchase power expenses for FY 2014 are forecast to range between $211 and $225 million.  October through April purchases totaled over $181 million – compared to $125 million for the same period last year.

Upper Great Plains Region

Storage: The NRCS’s snowpack conditions continue to be above average at 138 percent of the 30 year median; therefore the anticipated inflow for the May through July period is forecast to be 1883.0 thousand acre-feet (kAF) or 132 percent of the 30 year average. Streamflows into Bighorn Lake during April were 216 percent of average. On May 1, the NRCS measured the snow water content of the mountain snowpack in the Bighorn Basin at 134 percent of average. Based on the May 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the May-July runoff into Bighorn Lake is expected to equal 1,636,200 acre-feet (177 percent of average).

As of April 18, 2014, the storage level at Canyon Ferry was 1,330,194 acre-feet and the active conservation pool is 70.3 percent full. Storage at Yellowtail is 725,094 acre-feet and the active conservation pool is 71.0 percent full.

COE: Bird peaking has started once again at Garrison, Ft. Randall, and Gavins Point. The Piping Plover and Least Tern return annually to nest on the sand banks of the river. Periodically the plants will be releasing a pulse of water to ensure the birds nest near the tops of the sandbanks, thus preventing the nests from washing away if the river fluctuates. As of May 12, 2014, mountain snowpack between Ft. Peck and Garrison the snowpack is 119 percent. Currently the system storage is slightly below normal due to drought in 2012 but the greater than average snowpack will bring system storage to normal levels and also increase system generation to near normal for the year. Runoff is estimated to be 125 percent of normal. Forecast energy was raised to 9,691 GWh, up somewhat from last month. Average is 10,027 GWh.

Snow pack: April 1 forecasted runoff for calendar year 2014 is 32.0 million acre-feet (MAF). This runoff would be 127 percent of normal runoff.

FY Generation: The six main stem power plants generated 827 million kWh of electricity in April. Total energy production for 2014 is forecasted to be 9,691 GWh, up from 8,964 GWh forecasted in March. The long-term average is approximately 10 billion kWh.

Purchased Power: We are in the shoulder months of the generating season, and with loads being down prices have stayed in the low twenties for off-peak power and on-peak power ranging up to mid thirties.

Rocky Mountain Region

The LAP area continues to be drought free. The year to date reservoir inflow has been above average in the North Platte Basin and well above average in the Colorado River headwaters and Bighorn Basin. The overall LAP reservoir storage at the end of April was below average with gains in the Colorado-Big Thompson Project (CBT) and losses in the North Platte Basin since the end of last April. The snowpack was well above average starting the month and remains so as of this writing. The latest National Weather Service forecast indicates June through August temperatures will just as likely be above average as below average in Northern Colorado and Wyoming while the precipitation is more likely to be above average. The spring snow melt runoff is now forecast to be above average in all three basins and well above average overall due to the snowpack and favorable soil moisture and bank storage carrying over from the heavy fall storms.

LAP Water Conditions At-A-Glance

Reservoir Storage Snowpack Most Probable Reservoir Inflow 1,000 acre-feet inches snow water equivalent 1,000 acre-feet (April - July) beginning of % of beginning of % of May % of May average average May average average forecast average average

CBT 612.5 599.6 102% 431.8 346.8 125% 825.0 588.0 140%

North Platte 1,264.6 1,572.8 80% 463.2 393.5 118% 900.0 770.0 117%

Bighorn 1,681.0 1,672.0 101% 472.0 317.5 149% 2,268.3 1,315.0 172%

TOTAL 3,558.1 3,844.4 93% 1,367.0 1,057.8 129% 3,993.3 2,673.0 149%

Net At Plant Generation Projections (GWh)

Winter 13-14 555.3 718.0 77% 555.3 718.0 77% 555.3 718.0 77%

Summer 14 1,382.3 1,217.8 114% 1,313.1 1,217.8 108% 1,505.8 1,217.8 124%

TOTAL 2014 1,937.6 1,935.8 100% 1,868.4 1,935.8 97% 2,061.1 1,935.8 106%

The summer season generation is expected to fall between 108 percent and 124 percent of average. Reclamation operating plans project likely plant bypasses in the Bighorn Basin and about a 50 percent chance of an early summer Lake Granby spill due to heavy reservoir inflows. Heavy runoff and likely reduced water demand will result in nearly full East Slope CBT storage. If the possibly of a late summer spill of Lake Granby is low then conditions would be right for another curtailment of Adams Tunnel imports and associated CBT generation in the late summer as a means to improve water clarity in Grand Lake. If there is a water clarity operation this summer, there has also been a request to pump from Lake Granby to Shadow Mountain Reservoir during the operation to test the impact of pumping on Shadow Mountain Reservoir algae blooms that occur when there are no Adams Tunnel imports in the hottest summer months. The water pumped to Shadow Mountain Reservoir would immediately spill from the reservoir and run back downstream into Lake Granby. The pumping energy required for the test would either increase the purchases for LAP or reduce the sale of surplus LAP generation during the time of heaviest summer power demands.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 14,775,000 acre-feet, which is about 48 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (April 2014) were about 93 percent of average. Lake Powell elevation currently is about 3,580 feet, 120 feet from maximum reservoir level, and about 90 feet from the minimum generation level. Lake Powell elevation increased in April as spring runoff began entering the reservoir. Based on the current forecast, the May 24-Month study projects Lake Powell elevation will peak near approximately 3,616 feet near the end of June and end the water year near 3,610 feet with approximately 12.78 MAF in storage (52 percent capacity).

Note that projections of elevation and storage have uncertainty at this point in the season, primarily due to uncertainty regarding the spring runoff and resulting inflow to Lake Powell. Under the minimum probable inflow scenario, last updated in April, the projected summer peak is 3,599 feet and end of water year storage is 11.0 MAF (45 percent capacity). Under the maximum probable inflow scenario, updated in April, the projected summer peak is 3,632 feet and end of water year storage is 14.9 MAF (61 percent capacity). There is a 10 percent chance that inflows will be higher, resulting in higher elevation and storage, and 10 percent chance that inflows will be lower, resulting in lower elevation and storage.

Based on that inflow forecast, estimated SLCA/IP net generation for FY 2014 is 4,206 GWh as compared to 5,584 GWh based on the long-term historical average generation.

Estimated purchase power expenses for firming during the FY 2014 are about $54.8 million as compared to about $18.4 million based on long–term median historical releases. Purchase power availability in the region is good and prices are somewhat higher than usual for this time of year. Firming purchases for the last month have been averaging in the low $40s on-peak and upper $30s off-peak.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 13.538 MAF (14.111 MAF March 2014), 20.621 MAF (64-Year Historical Average).

The Lake Mead end of April 2014 elevation was 1,094.55 feet (7.16 feet lower than end of Mar 2014 elevation ), or about 125.09 feet below full storage elevation of 1,219.64 feet and 44.55 feet above the minimum generation elevation for Hoover of 1,050 feet.

Lake Mead’s elevation peaked at 1108.75 feet in January of water year (WY) 2014 (13.57 feet below the WY 2013 peak elevation of 1,122.32 feet), and is projected to drop to a minimum elevation of 1,081.18 feet in September of WY 2014, a maximum fluctuation in lake elevation of 27.57 feet.

The Lake Powell operational tier for WY 2014 is currently the Mid-Elevation Release Tier. Total releases from Lake Powell to Lake Mead are projected to average about 7.48 MAF for WY 2014 (actual of 8.232 MAF for WY 2013). The projected 2014 April-July unregulated inflow into Lake Powell (as of May 2, 2104) is 7.550 MAF or 105 percent of average (actual of 2.56 MAF or 36 percent of average for 2013).

Basin Snow Pack and Precipitation: DSW hydrology, or the Lower Colorado River Basin, is mostly dependent on the Colorado River Basin snow pack and precipitation above Lake Powell. The WY 2014 precipitation is currently 100 percent of average and the snowpack is 145 percent of the 30- year (1981-2010) median.

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for April 2014 was 17 kAF. The projected side inflow into Lake Mead for WY 2014 is 708 kAF which represents a 14 percent decrease over last year’s actual of 824 kAF, and represents 54 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2014 Generation: 5,316 GWh compared to 5,640 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2014 is 94 percent of the average historical generation.

Wholesale Power Market Conditions: The March market prices in the Desert Southwest averaged about $41/MWh firm on-peak, $32/MWh firm off-peak compared to $42/MWh firm on-peak, $33/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 4.873 million-acre-feet, compared to 7.615 MAF last year. Accumulated inflow for the water year-to-date is 34 percent of the 15-year average for Trinity, 49 percent for Shasta, 40 percent for Folsom and 39 percent for New Melones. None of the reservoirs is in flood control operations at this time.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. October recorded precipitation totaled 0.72 inches, or 23 percent of the monthly average. November recorded precipitation totaled 1.66 inches, or 26 percent of average. December came in at 0.92 inches, or 10 percent of average. January came in at 1.20 inches or 13 percent of its average. February ended at 14.20 inches or 130 percent of its average. March came in at 10.21 inches, or 153 percent of average. April ended at 3.95 inches or 67 percent of average. The cumulative total at this time is 28.80 inches or 57 percent of the annual average. December and January are the months with the highest average, with February very close. March is next and we received another 5 inches during the last week of that month. May which averages 2.20 inches is currently at 0.75.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak April 1. Snow water equivalents are reported as a percentage of this average. As of May 23, the North is at 2 percent, the Central is at 3 percent and the South is at 1 percent of this average. The Sacramento River Index forecast of water supply, based upon May 1 conditions forecast, remains “critical” for the 90 percent exceedence as well as the 50 percent case. The 40-30-30 year type declaration based upon May 1 conditions at the 50 percent exceedence level is “critical.”

Western Summary

 The most probable forecast of net generation for fiscal year (FY) 2014 is 23,421 gigawatt- hours (GWh) or 86 percent of average. October through May generation was 82 percent of average.  The lower level forecast of generation for FY 2014 is 22,640 GWh or 83 percent of average.  The purchased power for FY 2014 is expected to range between 4,386 and 4,634 GWh.  The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $50/megawatt-hour (MWh). This price compares to $45/MWh last year.  Purchase power expenses for FY 2014 are forecast to range between $221 and $231 million.  October through May purchases totaled over $194 million – compared to $141 million for the same period last year.

Cumulative of Actual Purchase Power Expenses - FY 14 $250

$225 Most Probable/Actual $200 Dry

$175

$150

$125

$100

$75

$50 Millions of Dollars of Millions

$25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month Upper Great Plains Region

Storage: The anticipated inflow for the June through July period is forecast to be 922.0 thousand acre-feet (kAF), or 97 percent of the 30-year average. Streamflows into Bighorn Lake during May were 203 percent of average. On June 1, the NRCS measured the snow water content of the mountain snowpack in the Bighorn Basin at 111 percent of average. Based on the June 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the June-July runoff into Bighorn Lake is expected to equal 782,900 acre-feet (119 percent of average).

As of June 24, 2014, the storage level at Canyon Ferry was 1,841,144 acre-feet and the active conservation pool is 97.3 percent full. Storage at Yellowtail is 925,249 acre-feet and the active conservation pool is 90.7 percent full.

COE: Bird peaking continues at Garrison and Ft. Randall. The Piping Plover and Least Tern return annually to nest on the sand banks of the river. Periodically the plants will be releasing a pulse of water to ensure the birds nest near the tops of the sandbanks, thus preventing the nests from washing away if the river fluctuates. Runoff is estimated to be 125 percent of normal. Forecast energy was raised to 9,691 GWh, up somewhat from last month. Average is 10,027 GWh.

Snow pack: April 1 forecasted runoff for calendar year 2014 is 32.0 million acre-feet (MAF). This runoff would be 127 percent of normal runoff. Mountain snowpack above Ft. Peck is currently 138 percent of normal. The mountain snowpack in the reach between Ft. Peck and Garrison is currently 142 percent of normal.

FY Generation: The six main stem power plants generated 880 million kilowatt-hours (kWh) of electricity in May. Total energy production for 2014 is forecasted to be 9,691 GWH, up from 8,964 GWh forecasted in March. The long-term average is approximately 10 billion kWh.

Purchased Power: We are starting the summer months of the generating season, and with loads increasing prices have stayed in the upper twenties for off-peak power and on-peak power ranges up to upper thirties.

Rocky Mountain Region

The LAP area continues to be drought free. The year to date reservoir inflow has been well above average. The overall LAP reservoir storage at the end of May was average with gains in the North Platte Basin and Colorado-Big Thompson Project (CBT) and losses in the Bighorn Basin since the end of last May. The snowpack was well above average starting the month and has mostly melted as of this writing which is normal. The latest National Weather Service forecast indicates July through September temperatures will more likely be below average while the precipitation is more likely to be above average. The spring snow melt runoff is still forecast to be above average in all three basins and well above average overall due to the snowpack and favorable soil moisture and bank storage carrying over from the heavy fall storms.

LAP Water Conditions At-A-Glance

Reservoir Storage Snowpack Most Probable Reservoir Inflow 1,000 acre-feet inches snow water equivalent 1,000 acre-feet (April - July) beginning of % of beginning of % of June % of June average average June average average forecast average average

CBT 733.5 673.3 109% 109.5 56.4 194% 937.0 588.0 159%

North Platte 1,646.7 1,725.8 95% 200.2 122.9 163% 1,000.0 770.0 130%

Bighorn 1,815.7 1,798.2 101% 149.9 108.1 139% 1,550.0 1,315.0 118%

TOTAL 4,195.9 4,197.3 100% 459.6 287.4 160% 3,487.0 2,673.0 130%

Net At Plant Generation Projections (GWh)

Winter 13-14 555.3 718.0 77% 555.3 718.0 77% 555.3 718.0 77%

Summer 14 1,409.5 1,217.8 116% 1,315.6 1,217.8 108% 1,528.4 1,217.8 126%

TOTAL 2014 1,964.8 1,935.8 101% 1,870.9 1,935.8 97% 2,083.7 1,935.8 108%

The summer season generation is expected to fall between 108 percent and 126 percent of average. Reclamation operating plans project likely plant bypasses in the Bighorn and North Platte basins and about a 50 percent chance of an early summer Lake Granby spill due to heavy reservoir inflows. Heavy runoff and likely reduced water demand will result in nearly full East Slope CBT storage. Another curtailment of Adams Tunnel imports and associated CBT generation has been planned for August as a means to improve water clarity in Grand Lake. There are now no plans to pump water from Lake Granby to Shadow Mountain Reservoir during the water clarity operation this year.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 17,090,000 acre feet, which is about 55 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (May 2014) were about 96 percent of average. Lake Powell elevation currently is about 3,600 feet, 100 feet from maximum reservoir level, and about 110 feet from the minimum generation level. Lake Powell elevation increased about 20 feet in May as spring runoff entered the reservoir. Based on the current forecast, the June 24-Month study projects Lake Powell elevation will peak near approximately 3,614 feet near the end of June and end the water year near 3,610 feet with approximately 12.715 MAF in storage (52 percent capacity).

Note that projections of elevation and storage have uncertainty, primarily due to uncertainty regarding the spring runoff and resulting inflow to Lake Powell. Under the minimum probable inflow scenario, last updated in April, the projected summer peak is 3,599 feet and end of water year storage is 11.0 MAF (45 percent capacity). Under the maximum probable inflow scenario, updated in April, the projected summer peak is 3,632 feet and end of water year storage is 14.9 MAF (61 percent capacity). There is a 10 percent chance that inflows will be higher, resulting in higher elevation and storage, and 10 percent chance that inflows will be lower, resulting in lower elevation and storage. The annual release volume from Lake Powell during water year (WY) 2014 is projected to be 7.48 MAF under all inflow scenarios.

Based on the most probable inflow forecast, estimated SLCA/IP net generation for FY 2014 is 4,124 GWh as compared to 5,584 GWh based on the long-term historical average generation.

Estimated purchase power expenses for firming during the FY 2014 are about $60.2 million as compared to about $21.7 million based on long–term average historical releases. Purchase power availability in the region is good and prices are somewhat higher than usual for this time of year. Firming purchases for the last month have been averaging in the mid $40s on-peak and mid $30s off-peak.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 12.954 MAF (13.538 MAF April 2014), 20.744 MAF (64-Year Historical Avg).

The Lake Mead end of May 2014 elevation was 1,087.46 feet (7.09 feet lower than end of Apr 2014 elevation), or about 132.18 feet below full storage elevation of 1,219.64 feet and 37.46 feet above the minimum generation elevation for Hoover of 1,050 feet.

Lake Mead’s elevation peaked at 1,108.75 feet in January of WY 2014 (13.57 feet below the WY 2013 peak elevation of 1,122.32 feet), and is projected to drop to a minimum elevation of 1,080.62 feet in September of WY 2014, a maximum fluctuation in lake elevation of 28.13 feet.

The Lake Powell operational tier for WY 2014 is currently the Mid-Elevation Release Tier. Total releases from Lake Powell to Lake Mead are projected to average about 7.48 MAF for WY 2014 (actual of 8.232 MAF for WY 2013). The projected 2014 April-July unregulated inflow into Lake Powell (as of June 16, 2014) is 7.26 MAF or 101 percent of average (actual of 2.56 MAF or 36 percent of average for 2013).

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for May 2014 was 14 kAF. The projected side inflow into Lake Mead for WY 2014 is 662 kAF which represents a 20 percent decrease over last year’s actual of 824 kAF, and represents 51 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2014 Generation: 5,318 GWh compared to 5,640 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2014 is 94 percent of the average historical generation.

Wholesale Power Market Conditions: The May market prices in the Desert Southwest averaged about $41/MWh firm on-peak, $30/MWh firm off-peak compared to $41/MWh firm on-peak, $32/MWh firm off-peak for the previous month. Sierra Nevada Region

The total storage of the four major CVP reservoirs is 4.233 MAF, compared to 6.815 MAF last year. Accumulated inflow for the water year-to-date is 30 percent of the 15-year average for Trinity, 49 percent for Shasta, 38 percent for Folsom, and 35 percent for New Melones. None of the reservoirs is in flood control operations at this time. Trinity storage is at 44 percent capacity, Shasta at 42 percent, Folsom nearly 50 percent, and New Melones is at 30 percent of its capacity. End of September carryover could be at an all-time low.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. October recorded precipitation totaled 0.72 inches, or 23 percent of the monthly average. November recorded precipitation totaled 1.66 inches, or 26 percent of average. December came in at 0.92 inches, or 10 percent of average. January came in at 1.20 inches or 13 percent of its average. February ended at 14.20 inches or 130 percent of its average. March came in at 10.21 inches, or 153 percent of average. April ended at 3.95 inches or 67 percent of average. May which averages 2.20 inches ended at 0.75 inches, only 34 percent of average. The cumulative total at this time is 28.80 inches or 57 percent of the annual average and there has been no measurable precipitation for June.

Western Summary

 The most probable forecast of net generation for fiscal year (FY) 2014 is 22,736 gigawatt- hours (GWh) or 84 percent of average. October through June generation was 82 percent of average.  The lower level forecast of generation for FY 2014 is 22,141 GWh or 82 percent of average.  The purchased power for FY 2014 is expected to be approximately 4,631 GWh.  The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to be $48/megawatt-hour (MWh). This price compares to $43/MWh last year.  Purchase power expenses for FY 2014 are forecast to be approximately $221 million.  October through June purchases totaled over $199 million – compared to $146 million for the same period last year.

Cumulative of Actual Purchase Power Expenses - FY 14 $250

$225 Most Probable/Actual $200 Dry

$175

$150

$125

$100

$75

$50 Millions of Dollars of Millions

$25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month Upper Great Plains Region

Canyon Ferry: The anticipated inflow for the June through July period for Canyon Ferry Dam and Reservoir is forecast to be 253.5 thousand acre-feet (kAF) or 90 percent of the 30-year average.

As of July 16, 2014, reservoir storage at Canyon Ferry was 1,893,223 acre-feet and the active conservation pool is 100.0 percent full.

Yellowtail: Streamflows into Bighorn Lake during June continued to remain above average at 128 percent of average. Based on the July 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the July runoff into Bighorn Lake is expected to equal 301,700 acre-feet (120 percent of average).

As of July 16, 2014, reservoir storage at Yellowtail is 1,026,532 acre-feet and the active conservation pool is 100.0 percent full.

COE: The large winter snowpack caused runoff in June to be 153 percent of normal above Garrison. Although the reaches above Fort Peck had better snowpack, runoff was less than expected due to dry conditions leaving Fort Peck lower than forecasted. Heavy rains in June between Garrison and Oahe added to these pool elevations. Flooding rains on the Big Sioux River in eastern South Dakota caused some large downstream flows below Gavins Point. System generation was cut back in recent weeks to allow this water to evacuate. Some of this energy has been pushed into the late fall and winter months to evacuate the system.

Bird peaking continues at Garrison and Fort Randall for the balance of the summer.

Snow pack: July forecasted runoff for 2014 is now 130 percent of normal at 33 million acre-feet (MAF). Normal runoff is 25.2 MAF.

FY Generation: The six main stem power plants generated 752 million kilowatt-hours (kWh) of electricity in June. Total energy production for 2014 is forecasted to be 9,332 GWH, down from 9,462 GWh forecasted in June. The long-term average is approximately 10 billion kWh.

Purchased Power: We are in the summer months of the generating season, and with loads increasing prices have stayed in the upper twenties for off-peak power and on-peak power ranges up to upper thirties.

Rocky Mountain Region

The LAP area continues to be drought free. The year-to-date reservoir inflow has been well above average. The overall LAP reservoir storage at the end of June was above average with gains in all three Basins since the end of last June. The latest National Weather Service forecast indicates August through October temperatures will more likely be below average while the precipitation is more likely to be above average. The total spring snowmelt runoff (April-July) will end up well above average in all three basins due to the snowpack and favorable soil moisture and bank storage carrying over from the heavy fall storms.

LAP Water Conditions At-A-Glance

Reservoir Storage Actual Reservoir Inflow To-Date Most Probable Reservoir Inflow 1,000 acre-feet 1,000 acre-feet 1,000 acre-feet (April - July) beginning of % of October % of July % of July average average - June average average forecast average average

CBT 928.5 797.5 116% 850.4 573.8 148% 770.3 588.0 131%

North Platte 1,951.3 1,837.5 106% 1,264.3 911.3 139% 1,045.0 770.0 136%

Bighorn 2,314.0 2,127.2 109% 1,750.3 1,282.8 136% 1,978.0 1,315.0 150%

TOTAL 5,193.8 4,762.2 109% 3,865.0 2,767.9 140% 3,793.3 2,673.0 142%

Net At Plant Generation Projections (GWh)

Winter 13-14 555.3 718.0 77% 555.3 718.0 77% 555.3 718.0 77%

Summer 14 1,372.3 1,217.8 113% 1,338.2 1,217.8 110% 1,413.7 1,217.8 116%

TOTAL 2014 1,927.6 1,935.8 100% 1,893.5 1,935.8 98% 1,969.0 1,935.8 102%

The summer season generation is expected to fall between 110 and 116 percent of average with a significant drop-off in August. There were plant bypasses in the Bighorn and North Platte basins due to the heavy spring runoff. Some of the Yellowtail bypass was at the request of Western to allow for upward regulation. In the CBT a bypass was required at the Green Mountain plant, and Lake Granby did start to spill when East Slope CBT storage filled. There will be a curtailment of Adams Tunnel imports and associated CBT generation from August 4 through the Labor Day weekend as a means to improve water clarity in Grand Lake. The amount of upcoming winter generation will depend on how much water remains in storage after the irrigation season winds down.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 18,102,000 acre-feet, which is about 59 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (June 2014) were about 115 percent of average. Lake Powell elevation currently is about 3,610 feet, 90 feet from maximum reservoir level, and about 120 feet from the minimum generation level. Lake Powell elevation has increased about 32 feet since March as spring runoff entered the reservoir. Based on the current forecast, the July 24-Month Study projects Lake Powell elevation will peak at approximately 3,610 feet and end the water year near 3,605 feet with approximately 12.25 MAF in storage (50 percent capacity).

Based on the most probable inflow forecast, estimated SLCA/IP net generation for FY 2014 is 4,091 GWh as compared to 5,584 GWh based on the long-term historical average generation.

Estimated purchase power expenses for firming during the FY 2014 are about $60.7 million as compared to about $21.7 million based on long-term average historical releases. Purchase power availability in the region is good and prices are somewhat higher than usual for this time of year. Firming purchases for the last month have been averaging in the mid $40s on-peak and mid $30s off-peak.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 12.505 MAF (12.954 MAF May 2014), 20.965 MAF (64-Year Historical Average).

The Lake Mead end of June 2014 elevation was 1,082.66 feet (4.8 feet lower than end of May 2014 elevation), or about 136.98 feet below full storage elevation of 1,219.64 feet and 32.66 feet above the minimum generation elevation for Hoover of 1,050 feet.

Lake Mead’s elevation peaked at 1,108.75 feet in January of water year (WY) 2014 (13.57 feet below the WY 2013 peak elevation of 1,122.32 feet), and is projected to drop to a minimum elevation of 1,080.17 feet in September of WY 2014, a maximum fluctuation in lake elevation of 28.58 feet.

The Lake Powell operational tier for WY 2014 is currently the Mid-Elevation Release Tier. Total releases from Lake Powell to Lake Mead are projected to average about 7.48 MAF for WY 2014 (actual of 8.232 MAF for WY 2013). The projected 2014 April-July unregulated inflow into Lake Powell (as of July 16, 2014) is 7.02 MAF or 98 percent of average (actual of 2.56 MAF or 36 percent of average).

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for June 2014 was 11 kAF. The projected side inflow into Lake Mead for WY 2014 is 649 kAF which represents a 27 percent decrease over last year’s actual of 824 kAF, and represents 50 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2014 Generation: 5,336 GWh compared to 5,640 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2014 is 95 percent of the average historical generation.

Wholesale Power Market Conditions: The June market prices in the Desert Southwest averaged about $45/MWh firm on-peak, $33/MWh firm off-peak compared to $41/MWh firm on-peak, $30/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 3,623 MAF, compared to 5.938 MAF last year. Accumulated inflow for the water year-to-date is 30 percent of the 15-year average for Trinity, 49 percent for Shasta, 38 percent for Folsom, and 35 percent for New Melones. None of the reservoirs is in flood control operations at this time. Trinity storage is at 37 percent capacity; Shasta at 36 percent, Folsom nearly 43 percent, and New Melones is at nearly 27 percent of its capacity. End of September carryover could be at an all-time low.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. October recorded precipitation totaled 0.72 inches, or 23 percent of the monthly average. November recorded precipitation totaled 1.66 inches, or 26 percent of average. December came in at 0.92 inches, or 10 percent of average. January came in at 1.20 inches or 13 percent of its average. February ended at 14.20 inches or 130 percent of its average. March came in at 10.21 inches, or 153 percent of average. April ended at 3.95 inches or 67 percent of average. May which averages 2.20 inches ended at 0.75 inches, only 34 percent of average. June which averages 0.97 inches ended at 0.05 inches. The cumulative total at this time is 28.97 inches or 57 percent of the annual average. July which averages 0.17 inches is at 0.12 inches now.

The average projection of net generation is again taken from the latest modeling using the update to our customers’ “Green Book.” This average, at 3.34 GWh, is less than the 3.63 GWh from the CVPIA PEIS planning studies. Under the Post 2004 Marketing Plan, net generation, after Project Use load, First Preference Customer load and sub-control area reserve requirement, becomes the Base Resource which is allocated among the Base Resource, Variable Resource and Full Load Service Customers. This past fiscal year ended at approximately 91 percent of that average. Reclamation forecasts are based upon January 1 conditions, which were based upon water supply forecast of “critical” for the 90 percent exceedence and “critical” for the 50 percent exceedence. These forecasts are 67 percent and 67 percent of this “Green Book” average net generation. Reclamation had been at 800 cubic feet per second (cfs) of pumping at Tracy for some time due to Delta outflow standard. Rather than release more water from storage, on July 10 they shut down Tracy and then began a two day on and one day off cycle. Meanwhile, State Water Project pumping has remained at 1,200 cfs during this time, with a Feather River release of approximately 3,000 cfs from Oroville. Hydro Conditions and Purchase Power Monthly Outlook August 2014

Western Summary

 The most probable forecast of net generation for fiscal year (FY) 2014 is 22,949 gigawatt- hours (GWh) or 85 percent of average. October through July generation was 84 percent of average.  The lower level forecast of generation for FY 2014 is 22,853 GWh or 84 percent of average.  The purchased power for FY 2014 is expected to be approximately 4,436 GWh.  The average price for purchase power during FY 2014 across all hydro projects and off-peak and on-peak periods is expected to be $50/megawatt-hour (MWh). The average price for FY 2013 was $41/MWh.  Purchase power expenses for FY 2014 are forecast to be approximately $222 million.  October through July purchases totaled over $206 million – compared to $155 million for the same period last year.

Cumulative of Actual Purchase Power Expenses - FY 14 $250

$225 Most Probable/Actual $200 Dry

$175

$150

$125

$100

$75

$50 Millions of Dollars of Millions

$25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month Upper Great Plains Region

Canyon Ferry: The anticipated inflow for August is forecast to be 135.0 thousand acre-feet (kAF) or 91 percent of the 30-year average. As of August 10, 2014, reservoir storage at Canyon Ferry was 1,796,812 acre-feet and the active conservation pool was 95 percent full.

Yellowtail: Streamflows into Bighorn Lake during June continued to remain above average at 140 percent of average. Based on the August 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the August runoff into Bighorn Lake was expected to equal 155,500 acre-feet (105 percent of average). As of August 10, 2014, reservoir storage at Yellowtail was 1,012,703 acre-feet and the active conservation pool is 99.2 percent full.

COE: The winter snowpack finished melting by the second week in July this year. System storage peaked on July 21 at 60.9 million acre-feet (MAF). The Fort Peck reservoir level remains a little below normal while the Garrison and Oahe levels are near normal. Warmer summer temperatures caused July precipitation to be below normal. The excessive runoff in June will provide additional energy into late fall and winter. System energy production for December through February should be 21,000 to 23,000 MWh daily. Bird peaking continues at Garrison and Fort Randall at least until the end of August.

Snow pack: August forecasted runoff for 2014 is now 129 percent of normal at 32.5 MAF. Normal runoff is 25.2 MAF.

FY Generation: The six main stem power plants generated 904 million kilowatt-hours of electricity in June. August forecasted energy production for the year dropped to 9,100 GWh, down from 9,332 GWh forecast in July. The 100-year average is approximately 10,027 GWh.

Rocky Mountain Region

The LAP area continues to be drought free. The year to date reservoir inflow has been well above average. The overall LAP reservoir storage at the end of July was above average with gains in all three Basins since the end of last July. The latest National Weather Service forecast indicates September through November temperatures will more likely be below average in Colorado while the precipitation is more likely to be above average. The temperatures and precipitation in Wyoming are just as likely to be above normal as below normal. The total spring snow melt runoff (April-July) was well above average in all three basins due to the snowpack and favorable soil moisture and bank storage carrying over from the heavy fall storms.

LAP Water Conditions At-A-Glance

Reservoir Storage Actual Reservoir Inflow To-Date Spring Reservoir Inflow 1,000 acre-feet 1,000 acre-feet 1,000 acre-feet (April - July) beginning of % of October % of % of August average average - July average average actual average average

CBT 947.1 776.4 122% 1,004.8 701.7 143% 860.3 588.0 146%

North Platte 1,729.9 1,636.5 106% 1,373.5 1,017.4 135% 1,078.9 770.0 140%

Bighorn 2,358.4 2,122.2 111% 2,211.1 1,572.9 141% 2,015.5 1,315.0 153%

TOTAL 5,035.4 4,535.1 111% 4,589.4 3,292.0 139% 3,954.7 2,673.0 148%

Net At Plant Generation Projections (GWh)

Winter 13-14 555.3 718.0 77% 555.3 718.0 77% 555.3 718.0 77%

Summer 14 1,361.7 1,217.8 112% 1,353.7 1,217.8 111% 1,371.7 1,217.8 113%

TOTAL 2014 1,917.0 1,935.8 99% 1,909.0 1,935.8 99% 1,927.0 1,935.8 100%

Winter 14-15 584.7 718.0 81% 539.6 718.0 75% 653.9 718.0 91%

The summer season generation is expected to fall between 111 and 113 percent of average with a significant drop-off in August. There were plant bypasses in the Bighorn and North Platte basins due to the heavy spring runoff. Some of the Yellowtail bypass was at the request of Western to allow for upward regulation. In the CBT a bypass was required at the Green Mountain plant and Lake Granby spilled when East Slope CBT storage filled. There is a curtailment of Adams Tunnel imports and associated CBT generation from August 11 through September 1 as a means to improve water clarity in Grand Lake. The amount of upcoming winter generation will depend on how much water remains in storage after the irrigation season winds down.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 17,877,000 acre-feet, which is about 58 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (July 2014) were about 88 percent of average. Lake Powell elevation currently is about 3,607 feet, 93 feet from maximum reservoir level, and about 117 feet from the minimum generation level. Based on the current forecast, the August 24-Month study projects Lake Powell elevation will end the water year near 3,604 feet with approximately 12.112 MAF in storage (50 percent capacity).

Based on the most probable inflow forecast, estimated SLCA/IP net generation for FY 2014 is 4,121 GWh as compared to 5,584 GWh based on the long-term historical average generation.

Estimated purchase power expenses for firming during FY 2014 are about $61.4 million as compared to about $21.7 million based on long-term average historical releases. Purchase power availability in the region is good and prices are somewhat higher than usual for this time of year. Firming purchases for the last month have been averaging in the mid $40s on-peak and low $30s off-peak.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 12.347 MAF (12.505 MAF June 2014), 20.860 MAF (64-Year Historical Average).

The Lake Mead end of July 2014 elevation was 1,080.60 feet (2.1 feet lower than end of June 2014 elevation), or about 139.04 feet below full storage elevation of 1,219.64 feet and 30.6 feet above the minimum generation elevation for Hoover of 1,050 feet.

Lake Mead’s elevation peaked at 1,108.75 feet in January of water year (WY) 2014 (13.57 feet below the WY 2013 peak elevation of 1,122.32 feet), and is projected to drop to a minimum elevation of 1,080.03 feet in September of WY 2014, a maximum fluctuation in lake elevation of 28.72 feet.

The Lake Powell operational tier for WY 2014 is currently the Mid-Elevation Release Tier. Total releases from Lake Powell to Lake Mead are projected to average about 7.48 MAF for WY 2014 (actual of 8.232 MAF for WY 2013). The projected 2014 April-July unregulated inflow into Lake Powell (as of August 18, 2014) is 6.923 MAF or 97 percent of average (actual of 2.56 MAF or 36 percent of average for 2013).

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for July 2014 was 55 kAF. The projected side inflow into Lake Mead for WY 2014 is 640 kAF which is a 22 percent decrease over last year’s actual of 824 kAF, and represents 49 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2014 Generation: 5,343 GWh compared to 5,639 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2014 is 95 percent of the average historical generation.

Wholesale Power Market Conditions: The July market prices in the Desert Southwest averaged about $46/MWh firm on-peak, $32/MWh firm off-peak compared to $45/MWh firm on-peak, $33/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 3.064 MAF, compared to 5.132 MAF this time last year. Accumulated inflow for the water year-to-date is 29 percent of the 15-year average for Trinity, 51 percent for Shasta, 41 percent for Folsom, and 36 percent for New Melones. None of the reservoirs is in flood control operations at this time. Trinity storage is at 29 percent capacity; Shasta at 31 percent, Folsom at 39 percent, and New Melones is at 23 percent of its capacity. End of September carryover could be at an all-time low.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. October recorded precipitation totaled 0.72 inches, or 23 percent of the monthly average. November recorded precipitation totaled 1.66 inches, or 26 percent of average. December came in at 0.92 inches, or 10 percent of average. January came in at 1.20 inches or 13 percent of its average. February ended at 14.20 inches or 130 percent of its average. March came in at 10.21 inches, or 153 percent of average. April ended at 3.95 inches or 67 percent of average. May which averages 2.20 inches ended at 0.75 inches, only 34 percent of average. June which averages 0.97 inches ended at 0.05 inches. July which averages 0.17 inches ended at 0.22 inches or 128 percent of average. The cumulative total at this time is 29.71 inches or 59 percent of the annual average.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak April 1. Snow water equivalents are reported as a percentage of this average. As of May 23, the North was at 2 percent, the Central is at 3 percent, and the South is at 1 percent of this average. The Sacramento River Index forecast of water supply, based upon May 1 conditions forecast, remains “critical” for the 90 percent exceedence as well as the 50 percent case. The 40-30-30 year type declaration based upon May 1 conditions at the 50 percent exceedence level is “critical.”

The average projection of net generation is again taken from the latest modeling using the update to our customers’ “Green Book.” This average, at 3.34 GWh, is less than the 3.63 GWh from the CVPIA PEIS planning studies. Under the Post 2004 Marketing Plan, net generation, after Project Use load, First Preference Customer load and sub-control area reserve requirement, becomes the Base Resource which is allocated among the Base Resource, Variable Resource and Full Load Service Customers. This past fiscal year ended at approximately 91 percent of that average. Reclamation forecasts are based upon January 1 conditions, which were based upon water supply forecast of “critical” for the 90 percent exceedence and “critical” for the 50 percent exceedence. These forecasts are 65 percent and 63 percent of this “Green Book” average net generation. Reclamation continues with their cycling of Delta pumping, causing them to pump 230 cubic feet per second (cfs), 570 cfs, or 800 cfs daily. Meanwhile, State Water Project pumping is now at 1,000 cfs, with a Feather River release of approximately 1,700 cfs from Oroville. Hydro Conditions and Purchase Power Monthly Outlook September 2014

Western Summary

 The most probable forecast of net generation for fiscal year (FY) 2014 is 23,110 gigawatt- hours (GWh) or 85 percent of average. October through August generation was 84 percent of average.  The lower level forecast of generation for FY 2014 is 22,926 GWh or 84 percent of average.  The purchased power for FY 2014 is expected to be approximately 4,512 GWh.  The average price for purchase power during FY 2014 across all hydro projects and off-peak and on-peak periods is expected to be $50/megawatt-hour (MWh). The average price for FY 2013 was $41/MWh.  Purchase power expenses for FY 2014 are forecast to be approximately $225 million.  October through August purchases totaled $216 million – compared to $169 million for the same period last year.

Cumulative of Actual Purchase Power Expenses - FY 14 $250

$225 Most Probable/Actual $200 Dry

$175

$150

$125

$100

$75

$50 Millions of Dollars of Millions

$25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep

Month

Upper Great Plains Region

Canyon Ferry: The anticipated inflow for September is forecast to be 191.9 thousand acre-feet (kAF) or 111 percent of the 30-year average. As of September 7, 2014, reservoir storage at Canyon Ferry was 1,736,611 acre-feet and the active conservation pool was 91.8 percent full.

Yellowtail: Streamflows into Bighorn Lake during August continued to remain above average at 135 percent of average. Based on the September 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the September runoff into Bighorn Lake is expected to equal 211,800 acre-feet (130 percent of average). As of September 7, 2014, reservoir storage at Yellowtail was 1,040,002 acre-feet and the active conservation pool was 100.0 percent full.

COE: Cooler than normal temperatures along with above normal runoff has been the story for the summer of 2014. Runoff was near record levels in August for the three largest reservoirs. Rains in Montana and the Dakotas have added to Fort Peck and Oahe reservoir levels. Releases at Gavins Point are normally 17,000 cubic feet per second (cfs) during the winter months, but are expected to be 20,000 cfs this winter due to the additional runoff. Spilling will take place at both Gavins Point and Fort Randall this fall to accommodate the additional water and annual maintenance at Fort Randall. System energy production for December through February should be 23,000 to 25,000 MWh daily. The September forecasted runoff for 2014 is now 141 percent of normal at 35.6 million acre-feet (MAF) (normal is 25.2 MAF).

FY Generation: The six main stem power plants generated 962 million kilowatt-hours of electricity in August. The September forecasted energy production for the year increased to 9,900 GWh, up from 9,100 GWh forecasted in August. 10,027 GWh is the 100-year average.

Purchased Power: We are in the fall months of the generating season and with loads decreasing, but more units offline for scheduled maintenance, prices are expected to be in the low $20s for off-peak power and the low $30s for on-peak power.

Rocky Mountain Region

The LAP area continues to be drought free. The year-to-date reservoir inflow has been well above average. The overall LAP reservoir storage at the end of August was above average with gains in all three Basins since the end of last August. The latest National Weather Service forecast indicates October through December temperatures will more likely be above normal in the Bighorn Basin in Wyoming and just as likely to be above normal as below normal elsewhere in Colorado and Wyoming. The precipitation is just as likely to be above normal as below normal in Colorado and Wyoming. The total spring snow melt runoff (April-July) was well above average in all three basins due to the snowpack and favorable soil moisture and bank storage carrying over from the heavy fall storms.

LAP Water Conditions At-A-Glance

Reservoir Storage Actual Reservoir Inflow To-Date Spring Reservoir Inflow 1,000 acre-feet 1,000 acre-feet 1,000 acre-feet (April - July) beginning of % of October % of % of September average average - August average average actual average average

CBT 913.8 718.9 127% 1,073.0 759.3 141% 860.3 599.4 144%

North Platte 1,487.1 1,296.3 115% 1,425.7 1,055.9 135% 1,139.8 781.0 146%

Bighorn 2,319.7 1,971.6 118% 2,354.8 1,668.5 141% 1,756.9 1,199.4 146%

TOTAL 4,720.6 3,986.8 118% 4,853.5 3,483.7 139% 3,757.0 2,579.8 146%

Net At Plant Generation Projections (GWh)

Winter 13-14 555.3 718.0 77% 555.3 718.0 77% 555.3 718.0 77%

Summer 14 1,356.0 1,217.8 111% 1,351.9 1,217.8 111% 1,360.7 1,217.8 112%

TOTAL 2014 1,911.3 1,935.8 99% 1,907.2 1,935.8 99% 1,916.0 1,935.8 99%

Winter 14-15 598.8 718.0 83% 578.1 718.0 81% 625.0 718.0 87%

The summer season generation is expected to total about 111 percent of average. There was a significant drop-off in August due to a curtailment of Adams Tunnel imports and associated CBT generation from August 11 through September 1 as a means to improve water clarity in Grand Lake. There were plant bypasses in the Bighorn and North Platte basins due to the heavy spring runoff. Some of the Yellowtail bypass was at the request of Western to allow for upward regulation. In the CBT a bypass was required at the Green Mountain plant and Lake Granby spilled when East Slope CBT storage filled. The amount of upcoming winter generation will depend on how much water remains in storage after the irrigation season winds down.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 17,607,000 acre-feet, which is about 57 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (August 2014) were about 106 percent of average. Lake Powell elevation currently is about 3,606 feet, 94 feet from maximum reservoir level, and about 116 feet from the minimum generation level. Based on the current forecast, the September 24-Month study projects Lake Powell elevation will end the water year near 3,604 feet with approximately 12.112 MAF in storage (50 percent capacity).

Based on the most probable inflow forecast, estimated SLCA/IP net generation for FY 2014 is 4,160 GWh as compared to 5,584 GWh based on the long-term historical average generation.

Estimated purchase power expenses for firming during FY 2014 are about $61.5 million as compared to about $21.7 million based on long-term average historical releases. Purchase power availability in the region is good and prices are typical for this time of year. Firming purchases for the last month have been averaging in the low $30s off-peak and mid $40s on-peak.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 12.396 MAF (12.347 MAF July-2014), 20.728 MAF (64-Year Historical Avg). The Lake Mead end of August 2014 elevation was 1,081.55 feet (0.95 feet higher than end of July 2014 elevation ), or about 138.09 feet below full storage elevation of 1,219.64 feet and 31.6 feet above the minimum generation elevation for Hoover of 1,050 feet. Lake Mead’s elevation peaked at 1,108.75 feet in January of water year (WY) 2014 (13.57 feet below the WY 2013 peak elevation of 1,122.32 feet), and is projected to drop to a minimum elevation of 1,080.07 feet in September of WY 2014, a maximum fluctuation in lake elevation of 28.68 feet. The Lake Powell operational tier for WY 2014 is currently the Mid- Elevation Release Tier. Total releases from Lake Powell to Lake Mead are projected to average about 7.48 MAF for WY 2014 (actual of 8.232 MAF for WY 2013). The observed 2014 April-July unregulated inflow into Lake Powell (as of September 10, 2014) was 6.923 MAF or 97 percent of average (actual of 2.56 MAF or 36 percent of average for 2013).

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for August 2014 was 112 kAF. The projected side inflow into Lake Mead for WY 2014 is 635 kAF which represents a 30 percent decrease over last year’s actual of 824 kAF, and represents 49 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2014 Generation: 5,307 GWh compared to 5,637 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2014 is 94 percent of the average historical generation.

Wholesale Power Market Conditions: The August market prices in the Desert Southwest averaged about $41/MWh firm on-peak, $32/MWh firm off-peak compared to $46/MWh firm on-peak, $32/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 2.668 MAF, compared to 4.661 MAF this time last year. Accumulated inflow for the water year-to-date is 29 percent of the 15-year average for Trinity, 52 percent for Shasta, 42 percent for Folsom, and 36 percent for New Melones. None of the reservoirs is in flood control operations at this time. Trinity storage is at 25 percent capacity; Shasta at 26 percent, Folsom at 36 percent, and New Melones is at 21 percent of its capacity. End of September carryover could be at an all-time low.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. October recorded precipitation totaled 0.72 inches, or 23 percent of the monthly average. November recorded precipitation totaled 1.66 inches, or 26 percent of average. December came in at 0.92 inches, or 10 percent of average. January came in at 1.20 inches or 13 percent of its average. February ended at 14.20 inches or 130 percent of its average. March came in at 10.21 inches, or 153 percent of average. April ended at 3.95 inches or 67 percent of average. May which averages 2.20 inches ended at 0.75 inches, only 34 percent of average. June which averages 0.97 inches ended at 0.05 inches. July which averages 0.17 inches ended at 0.22 inches or 128 percent of average. August which averages 0.27 inches ended at 0.64 inches. September which averages 0.79 inches was at 0.59 inches as of September 25, 2014. The cumulative total on that date was 30.3 inches or 60 percent of the annual average.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak as of April 1. Snow water equivalents are reported as a percentage of this average. As of May 23, the North is at 2 percent, the Central is at 3 percent and the South is at 1 percent of this average. The Sacramento River Index forecast of water supply, based upon the May 1 conditions forecast, remains “critical” for the 90 percent exceedence as well as the 50 percent case. The 40-30-30 year type declaration based upon May 1 conditions at the 50 percent exceedence level is “critical.”

The average projection of net generation is again taken from the latest modeling using the update to our customers’ “Green Book.” This average, at 3.34 GWh, is less than the 3.63 GWh from the CVPIA PEIS planning studies. Under the Post 2004 Marketing Plan, net generation, after Project Use load, First Preference Customer load and sub-control area reserve requirement, becomes the Base Resource which is allocated among the Base Resource, Variable Resource and Full Load Service Customers. This past fiscal year ended at approximately 91 percent of that average. Reclamation forecasts are based upon January 1 conditions, which were based upon water supply forecast of “critical” for the 90 percent exceedence and “critical” for the 50 percent exceedence. These forecasts are both 60 percent of this “Green Book” average net generation. Reclamation stopped the cycling of Delta pumping due to a problem with the State’s pumping. Reclamation is currently at two units of pumping and is providing 1 kAF of water to the State. Hydro Conditions and Purchase Power Report October 2014

Western Summary

• Fiscal year (FY) 2014 ended with net generation of 22,938 gigawatt-hours (GWh), or 88 percent of average. • The amount of power purchased for FY 2014 was 4,547 GWh, compared to FY 2013 purchases of 4,428 GWh. • The average price for purchase power across all hydro projects and off-peak and on-peak periods was $50/megawatt-hour (MWh). The average price for FY 2013 was $41/MWh. • Purchase power expenses for FY 2014 were $226.4 million, compared to $181.5 million for FY 2013. The breakdown for the FY 2014 purchases, in millions, is: UGPR - $80.0, RMR - $21.1, CRSP - $62.0, DSW - $5.7, and SNR - $57.6.

Cumulative of Actual Purchase Power Expenses - FY 14 $250

$225

$200

$175

$150

$125

$100

$75

$50 Millionsof Dollars

$25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep

Month Upper Great Plains Region

Canyon Ferry: The anticipated inflow for October is forecast to be 282.1 thousand acre-feet (kAF) or 114 percent of the 30-year average. As of October 8, 2014, reservoir storage at Canyon Ferry was 195,589 acre-feet and the active conservation pool was 89.7 percent full.

Yellowtail: Streamflows into Bighorn Lake during September were 135 percent of average. Based on the October 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the October runoff into Bighorn Lake is expected to equal 187,600 acre- feet or 117 percent of average. As of October 8, 2014, reservoir storage at Yellowtail was 1,007,279 acre-feet and the active conservation pool was 98.7 percent full.

COE: Several large rainfall events in September caused above normal runoff to persist on the Missouri River system, which continues to keep the three largest reservoirs above normal heading into the winter season. System storage peaked in September with 61.3 million acre-feet (MAF). Gavins Point releases are expected to be 20,000 cubic feet per second through the winter due to the continued runoff, and energy production this winter looks to be better than the last few years. The October forecasted runoff for 2014 remains at 35.5 MAF or 141 percent of normal. Normal runoff is 25.2 MAF. The October forecasted energy production for the year decreased slightly to 9,818 GWh. This is down from the September forecast of 9,898 GWh.

FY Generation: The six main stem power plants generated 1,043 GWh of electricity in September, and the total energy production for FY 2014 was 9,571 GWh. 10,027 GWh is the 100-year average.

Purchased Power: We are in the fall months of the generating season, and with loads decreasing but more units offline for scheduled maintenance, prices are expected to be in the mid $20s for off-peak power and the mid $30s for on-peak power.

Rocky Mountain Region

The LAP area continues to be drought free. The snowpack peaked at the normal time this year with peaks of 135 percent of average in the Bighorn Basin, 112 percent in the North Platte, and 140 percent in the Upper Colorado headwaters of the Colorado-Big Thompson Project (CBT). Good soil moisture and stream bank storage carrying over from a very wet fall season and a very good snowpack resulted in reservoir inflows that were well above average in all three river basins. Water demands were below normal due to a rather cool and wet summer and the resulting overall LAP reservoir storage at the end of September was above average with gains in all three river basins since last September. The latest National Weather Service forecast indicates November through January temperatures will more likely be above average in Wyoming with an equal chance of being above or below normal in Colorado. The precipitation in that same period is just as likely to be above as below average in Colorado and all but the northwest portion of Wyoming. The precipitation is more likely to be below average in Wyoming’s Bighorn Basin.

LAP Water Conditions At-A-Glance Net At Plant Generation Projections (GWh)

Reservoir Storage Actual Annual Reservoir Inflow FY2014 Actual Generation 1,000 acre-feet 1,000 acre-feet FY2015 Winter Projection end of % of % of % of FY2014 average average FY2014 average average average average

CBT 864.4 699.9 124% 1,123.0 792.0 142% Winter 13-14 555.3 718.0 77%

North Platte 1,425.2 1,209.7 118% 1,470.7 1,081.1 136% Summer 14 1,336.3 1,217.8 110%

Bighorn 2,198.6 1,899.9 116% 2,442.1 1,741.6 140% TOTAL 2014 1,891.6 1,935.8 98%

TOTAL 4,488.2 3,809.5 118% 5,035.8 3,614.7 139% Winter 14-15 551.1 718.0 77%

LAP generation was near average in FY 2014, with the winter generation well below average and the summer generation above average. There was an extended CBT outage due the flooding last September. Reclamation drained Lake Estes and curtailed all imports through Adams Tunnel through early December to allow for the removal of sediment and debris washed into the Lake by the flood. Imports resumed in mid-December and heavier Adams Tunnel imports later in the winter shifted normal October and November CBT generation into February and March. There were minimum winter reservoir releases and associated generation in the North Platte Basin due to depleted reservoir storage.

There were plant bypasses in the Bighorn and North Platte basins in the spring due to the heavy snowmelt runoff. Some of the Yellowtail bypass was at the request of Western to allow for upward on-peak regulation in the WACM balancing authority while other load following plants were loaded to capacity. In the CBT a bypass was required at the Green Mountain plant and Lake Granby spilled when East Slope CBT storage filled. The generation was, however, below average in August due to a curtailment of Adams Tunnel imports and associated CBT generation from August 11 through the September 1 as a means to improve water clarity in Grand Lake.

Winter generation is based on reservoir storage at the end of the irrigation season and reservoir releases required to achieve spring reservoir storage targets. Spring reservoir targets may be modified as mountain snowpack develops over the winter and early spring. The upcoming winter season generation is expected to be about 77 percent of average and seasonal energy purchases have been arranged to support LAP firm electric service commitments.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 17,636,000 acre-feet, which is about 57 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (September 2014) were about 131 percent of average. Lake Powell elevation currently is about 3,606 feet, 94 feet from maximum reservoir level and about 116 feet from the minimum generation level. Based on the current forecast, the October 24- Month study projects Lake Powell elevation will end the water year near 3,605 feet with approximately 12.286 MAF in storage (51 percent capacity).

Based on the most probable inflow forecast, estimated SLCA/IP net generation for FY 2014 is 4,160 GWh as compared to 5,584 GWh based on the long-term historical average generation.

Purchase power expenses for firming during FY 2014 were $62 million, as compared to about $21.7 million based on long-term average historical releases. Purchase power availability in the region is good and prices are typical for this time of year. Firming purchases for the last month have been averaging in the low $30s off-peak and low $40s on-peak.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 12.349 MAF (12.396 MAF August 2014), 20.614 MAF (64-Year Historical Average). The Lake Mead end-of-September 2014 elevation was 1,081.33 feet (0.22 feet lower than end of August 2014 elevation), or about 138.31 feet below full storage elevation of 1,219.64 feet and 31.33 feet above the minimum generation elevation for Hoover of 1,050 feet. Lake Mead’s elevation peaked at 1,108.75 feet in January of water year (WY) 2014 (13.57 feet below the WY 2013 peak elevation of 1,122.32 feet), and dropped to a minimum elevation of 1,080.6 feet in July of WY 2014, a maximum fluctuation in lake elevation of 28.15 feet. The Lake Powell operational tier for WY 2014 was the Mid- Elevation Release Tier. Total releases from Lake Powell to Lake Mead were 7.48 MAF for WY 2014 (actual of 8.232 MAF for WY 2013). The observed 2014 April-July unregulated inflow into Lake Powell was 6.923 MAF or 97 percent of average (actual of 2.56 MAF or 36 percent of average for 2013).

Basin Snow Pack and Precipitation: DSW hydrology, or the Lower Colorado River Basin, is mostly dependent on the Colorado River Basin snow pack and precipitation above Lake Powell. WY 2014 ended with a precipitation of 106 percent of average. Observed precipitation for September was 125 percent. Forecasted precipitation for October is 146 percent, November is 106 percent, and December is 105 percent.

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for September 2014 was 138 kAF. The observed side inflow into Lake Mead for WY 2014 was 675 kAF which represents a 18 percent decrease over last year’s actual of 824 kAF, and 52 percent of the normal annual side inflow of 1.3 MAF.

Actual WY 2014 Generation (Parker, Davis & Hoover): 5,311 GWh compared to 5,636 GWh (Historical Average). The actual Hoover and Parker-Davis generation for WY 2014 was 94 percent of the average historical generation.

Wholesale Power Market Conditions: The September market prices in the Desert Southwest averaged about $41/MWh firm on-peak and $32/MWh firm off-peak, compared to $41/MWh firm on-peak and $32/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 2.629 MAF, compared to 4.841 MAF last year. The water year ended on September 30 with 2.212 MAF less storage than last water year. Accumulated inflow for the water year ended at 29 percent for Trinity, 52 percent for Shasta, 42 percent for Folsom, and 36 percent for New Melones. The Northern Sierra Eight Station Index averages slightly more than 50 inches of precipitation per water year. October recorded precipitation totaled 0.72 inches, or 23 percent of the monthly average. November recorded precipitation totaled 1.66 inches, or 26 percent of average. December came in at 0.92 inches, or 10 percent of average. January came in at 1.20 inches, or 13 percent of its average. February ended at 14.20 inches, or 130 percent of its average. March came in at 10.21 inches, or 153 percent of average. April ended at 3.95 inches, or 67 percent of average. May, which averages 2.20 inches, ended at 0.75 inches or only 34 percent of average. June, which averages 0.97 inches, ended at 0.05 inches. July, which averages 0.17 inches, ended at 0.22 inches or 128 percent of average. Augus,t which averages 0.27 inches, ended at 0.64 inches. September, which averages 0.79 inches, ended at 1.63 inches. The cumulative total for the water year was 31.34 inches, or 62 percent of the annual average.

The snowpack is assumed to reach its peak April 1. Snow water equivalents are reported as a percentage of this average. By June 9, the snowpack was gone. The Sacramento River Index forecast of water supply, based upon the May 1 conditions forecast, was “critical” for the 90 percent exceedence as well as the 50 percent case. The 40-30-30 year type declaration based upon May 1 conditions at the 50 percent exceedence level was also “critical.”

Hydro Conditions and Purchase Power Monthly Outlook January 2015

Western Summary

• The most probable forecast of net generation for fiscal year (FY) 2015 is 24,754 gigawatt- hours (GWh) or 94 percent of average. October through December generation was 97 percent of average. • The lower level forecast of generation for FY 2015 is 23,590 GWh or 89 percent of average. • The amount of power purchased for FY 2015 is expected to range between 2,110 and 2,899 GWh. • The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to range between $49/megawatt-hour (MWh) and $55/MWh for FY 2015 – compared to an actual average price of $50/MWh for FY 2014. • Purchase power expenses are forecast to range between $117 and $142 million for FY 2015 – compared to actual purchase power expenses of $226 million in FY 2014. • October through December purchases totaled $36 million – compared to $69 million for the same timeframe the year before.

Cumulative of Actual Purchase Power Expenses - FY 15 $150

Most $125 Probable/Actual Dry

$100

$75

Millions of Dollars $50

$25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep

Month

Upper Great Plains Region

Corps of Engineers Report: Run-off for 2014 ended up at 25.6 million acre-feet (MAF), which ranks eleventh in the past 118 years on record. The December system storage remained stable and the forecasted energy production was increased along with releases due to cold temperatures and icing over of the reservoirs. Gavins Point winter release has been increased to 20,000 cubic feet per second (cfs) for the next couple of months which is up from the 17,000 cfs in December. System storage peaked in September with 61.3 MAF and has since dropped to 56.4 MAF at the end of December. This is slightly above the Base Flood Control level.

Snowpack: The snowpack at Canyon Ferry and Yellowtail started out below normal this fall but ended near 100 percent in December. The snowpack above Fort Peck is 101 percent and from Fort Peck to Garrison is 101 percent of normal. Light plains snow pack has accumulated in the Dakotas.

Canyon Ferry: As of January 13, 2015, reservoir storage was 1,573,686 acre-feet and the active conservation pool was 83.2 percent full. The anticipated inflow for the April-July spring runoff period is forecast to be 1,867,800 acre-feet or 110 percent of the 30-year average.

Yellowtail: As of January 13, 2015, reservoir storage at is 909,589 acre-feet and the active conservation pool is 89.1 percent full. Streamflows into Bighorn Lake during December were 134 percent of average. Based on the January 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the April-July runoff into Bighorn Lake is expected to equal 1,095,700 acre-feet or 101 percent of average.

Generation: Water year (WY) 2014 ended with energy production of 9,574 GWh. This is down from the December forecast of 9,602 GWh. The six main stem power plants generated 606 million kilowatt-hours of electricity in December.

Purchase Power: UGPR is in the winter months of the generating season and with loads increasing, prices are expected to be in the low thirties for off-peak power and the mid forties for on-peak power.

Rocky Mountain Region

The LAP area is drought free and an improvement over last January. The snowpack ranged from below average to well above average at the beginning of the month. Reservoir inflows have been well above average so far due to good precipitation this fall and early winter. The

overall LAP reservoir storage at the end of December was well above average with gains in all three basins since the end of last December. The latest National Weather Service forecast indicates February through April temperatures will more likely be above average in western Wyoming and just as likely to be above as below average in southeast Wyoming and Colorado. The same forecast indicates precipitation will just as likely be above average as below average in Wyoming and more likely to be above average in Colorado.

LAP Water Conditions At-A-Glance

CBT 821.1 661.1 124% 142.1 118.3 120% 89.4 58.7 152%

North Platte 1,575.9 1,344.7 117% 137.6 146.1 94% 119.9 99.2 121%

Bighorn 2,077.2 1,825.3 114% 148.1 142.8 104% 260.1 200.6 130%

TOTAL 4,474.2 3,831.1 117% 427.8 407.2 105% 469.4 358.5 131%

Net At Plant Generation Projections (GWh)

Winter 13-14 536.7 718.0 75% 531.8 718.0 74% 577.5 718.0 80%

Summer 14 1,401.6 1,217.8 115% 1,181.5 1,217.8 97% 1,594.2 1,217.8 131%

TOTAL 2014 1,938.3 1,935.8 100% 1,713.3 1,935.8 89% 2,171.7 1,935.8 112%

The winter season generation is expected to be about 75 percent of average and seasonal energy purchases have been arranged to support LAP firm electric service commitments. Adams Tunnel imports from the west slope and associated generation will be well above normal this winter because the east slope storage space is limited after low water demands last year. Winter reservoir releases and associated generation in the North Platte Basin will be typical of recent operations and the release from Bighorn Lake via the Yellowtail power plant is above average under the latest Bighorn Lake operating criteria. The upcoming summer LAP generation is projected to be between 89 percent and 112 percent of average at this time.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 16,507,000 acre-feet, which is about 53 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (December 2014) were about 115 percent of average. Lake Powell elevation currently is about 3,596 feet, 104 feet from maximum reservoir level and about 106 feet from the minimum generation level. Based on the current forecast,

the January 24-Month Study projects Lake Powell elevation will end the water year near 3,609 feet with approximately 12.631 MAF in storage (52 percent capacity).

Based on the most probable inflow forecast, estimated SLCA/IP net generation for FY 2015 is 5,040 GWh as compared to 5,571 GWh based on the long-term historical average generation.

Purchase power expenses for firming during FY 2015 are estimated at $17.8 million as compared to about $21.5 million based on long-term average historical releases. Purchase power availability in the region is good and prices are low for this time of year. Firming purchases for the last month have been averaging in the high $30s on-peak and low $30s off- peak.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 12.774 MAF (12.405 MAF November 2014), 20.694 MAF (65-Year Historical Average).

The Lake Mead end of December 2014 elevation was 1,087.79 feet (4.22 feet higher than end of November 2014 elevation), or about 131.85 feet below full storage elevation of 1,219.64 feet and 37.79 feet above the minimum generation elevation for Hoover of 1,050 feet.

Lake Mead’s elevation is projected to peak at 1088.98 feet in February of WY 2015 (19.77 feet below the WY 2014 peak elevation of 1,108.75 feet), and drop to a minimum elevation of 1,072.95 feet in June of WY 2015. This projected minimum elevation is below the 1,075 feet Shortage Condition elevation; however, this does not mean that Lake Mead would be operating under Shortage Conditions for WY 2015. Lake Mead is currently operating under Normal Conditions for WY 2015. Lake Mead’s elevation at the beginning of WY 2015 (October 1, 2014) was 25.4 feet lower than at the beginning of WY 2014 (October 1, 2013).

The Lake Powell operational tier for WY 2015 is currently the Upper Elevation Balancing Tier. Total releases from Lake Powell are projected to average about 9.0 MAF for WY 2015 (actual of 7.48 MAF for WY 2014). These releases above the normal 8.23 MAF are characterized as “balancing releases” due to the current projection that the Lake Powell elevation will be at or above 3,575 feet and the Lake Mead elevation will be below 1,075 feet on September 30, 2015. The projected April-July unregulated inflow into Lake Powell is 6.50 MAF or 91 percent of average (actual of 6.92 MAF or 97 percent of average for 2014).

Basin Snow Pack and Precipitation: DSW hydrology, or the Lower Colorado River Basin, is mostly dependent on the Colorado River Basin snow pack and precipitation above Lake Powell. The WY 2015 precipitation is currently 82 percent of average and the snowpack is 86 percent of average.

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for December 2014 was 67 thousand acre-feet (kAF). The projected side inflow into Lake Mead for WY 2015 is 839 kAF which represents a 20.4 percent increase over last year’s actual of 677 kAF, and represents 65 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2015 Generation: 5,164 GWh compared to 5,633 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2015 is 92 percent of the average historical generation.

Wholesale Power Market Conditions: The December market prices in the Desert Southwest averaged about $31/MWh firm on-peak, $24/MWh firm off-peak compared to $38/MWh firm on-peak, $33/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 3.821 MAF, compared to 4.045 MAF last year. Accumulated inflow for the water year-to-date is 155 percent of the 15-year average for Trinity, 102 percent for Shasta, 68 percent for Folsom, and 62 percent for New Melones. None of the reservoirs is in flood control operations at this time.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak on April 1. Therefore, snow water equivalents are reported as a percentage of this average. As of January 20, the North is at 18 percent, the Central is at 16 percent, and the South is at 15 percent of this average. The Sacramento River Index forecast of water supply based upon January 1 conditions is “dry” for the 90 percent exceedance, but “above normal” for the 50 percent case, expecting quite a different picture based upon February 1 conditions given this month’s dryness.

The average projection of net generation is again taken from the latest modeling using the update to our customers’ “Green Book.” This average, at 3.34 GWh, is less than the 3.63 GWh from the Central Valley Project Improvement Act Programmatic Environmental Impact Statement planning studies. Under the Post 2004 Marketing Plan, net generation, after Project Use load, First Preference Customer load and sub-control area reserve requirement, becomes the Base Resource which is allocated among the Base Resource, Variable Resource and Full Load Service Customers. The past fiscal year ended at approximately 60 percent of that

average. The Bureau of Reclamation forecasts are based upon December 1 conditions, which were based upon water supply forecast of “critical” for the 90 percent exceedence and “below normal” for the 50 percent exceedance Sacramento River Index. These forecasts would be 51 percent and 61 percent of this “Green Book” average net generation, and more indicative of current dry conditions.

Hydro Conditions and Purchase Power Monthly Outlook February 2015

Western Summary

• The most probable forecast of net generation for fiscal year (FY) 2015 is 25,184 gigawatt- hours (GWh) or 93 percent of average. October through January generation was 92 percent of average. • The lower level forecast of generation for FY 2015 is 24,043 GWh or 89 percent of average. • The amount of power purchased for FY 2015 is expected to range between 2,088 and 2,627 GWh. • The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to range between $49/megawatt-hour (MWh) and $56/MWh for FY 2015 – compared to an actual average price of $50/MWh for FY 2014. • Purchase power expenses are forecast to range between $116 and $130 million for FY 2015 – compared to actual purchase power expenses of $226 million in FY 2014. • October through December purchases totaled $54 million – compared to $99 million for the same timeframe the year before.

Cumulative of Actual Purchase Power Expenses - FY 15 $150

Most $125 Probable/Actual Dry

$100

$75

Millions of Dollars $50

$25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month

Upper Great Plains Region

Corps of Engineers Report: A January thaw was responsible for larger than normal runoff during the month. As of February 1, the system storage rose slightly and the forecasted energy production was increased along with releases. The February forecast runoff for 2015 is 25.5 million acre-feet (MAF), slightly above the average of 25.2 MAF. System storage peaked in September 2014 with 61.3 MAF and has since dropped to 56.5 MAF as of February 1, 2015. This is still slightly above the Base Flood Control level of 56.1 MAF.

Snowpack: The snow pack at Yellowtail and Canyon Ferry started out below normal this fall but was 99 percent at the end of January. The main stem snowpack as of February 1 is 93 percent above Fort Peck and 96 percent on the reach from Fort Peck to Garrison. Only a light plains snow pack has accumulated in the Dakotas.

Canyon Ferry: As of February 10, 2015, reservoir storage at Canyon Ferry was 1,552.4 thousand acre-feet (kAF) and the active conservation pool was 82.1 percent full. The anticipated inflow for the April-July spring runoff period is forecast to be 1,661.7 kAF or 98 percent of the 30-year average.

Yellowtail: As of February 11, 2015, reservoir storage at Yellowtail is 902,921 acre-feet and the active conservation pool is 88.5 percent full. Streamflows into Bighorn Lake during January were 129 percent of average. On February 1, the Natural Resources Conservation Service measured the snow water content of the mountain snowpack in the Bighorn Basin at 90 percent of average. Based on the February 1 water supply forecast and the planned releases out of Boysen and Buffalo Bill Reservoirs, the April-July runoff into Bighorn Lake is expected to equal 1,015.8 kAF or 94 percent of average.

Generation: The six main stem power plants generated 680 million kilowatt-hours of electricity in December.

Purchase Power: UGPR is in the winter months of the generating season and with loads increasing, prices are expected to be in the low $30s for off-peak power and the mid $40s for on-peak power.

Rocky Mountain Region

Moderate drought conditions have returned to the Colorado River headwaters above Lake Powell, but the extreme upper headwaters above Kremmling that supply the Colorado-Big

Thompson Project (CBT) are not yet affected. The snowpack was well below average in the North Platte Basin above Seminoe Dam and average in the Bighorn Basin above Yellowtail Dam and the Upper Colorado River headwaters above Kremmling at the beginning of the month. Reservoir inflows have been well above average since September due to good precipitation this fall and winter. The overall LAP reservoir storage at the end of January was above average with gains in all three basins since the end of last January. The latest National Weather Service forecast indicates March through May temperatures will more likely be above average in western Wyoming and just as likely to be above as below average in eastern Wyoming and Colorado. The same forecast indicates precipitation will more likely be above average in Wyoming and Colorado. The Bureau of Reclamation (Reclamation) is forecasting reservoir inflows to be well below average in the North Platte Basin, below average in the Bighorn Basin, and above average for the CBT.

LAP Water Conditions At-A-Glance

CBT 813.3 649.9 125% 288.2 289.0 100% 625.0 599.0 104%

North Platte 1,623.3 1,381.3 118% 201.1 272.1 74% 450.0 694.0 65%

Bighorn 2,029.8 1,772.3 115% 249.9 247.0 101% 1,280.0 1,321.1 97%

TOTAL 4,466.4 3,803.5 117% 739.2 808.1 91% 2,355.0 2,614.1 90%

Net At Plant Generation Projections (GWh)

Winter 14-15 533.7 718.0 74% 525.5 718.0 73% 523.0 718.0 73%

Summer 15 1,366.0 1,217.8 112% 1,134.9 1,217.8 93% 1,487.3 1,217.8 122%

TOTAL 2015 1,899.7 1,935.8 98% 1,660.4 1,935.8 86% 2,010.3 1,935.8 104%

The winter season generation is expected to be about 73 percent of average and seasonal energy purchases have been arranged to support LAP firm electric service commitments. CBT Adams Tunnel imports from the west slope and associated generation will be well below normal this winter because the east slope storage space is limited after low water demands last year. Winter reservoir releases and associated generation in the North Platte Basin will be typical of recent operations and the release from Bighorn Lake via the Yellowtail power plant is above average under the latest Bighorn Lake operating criteria. The upcoming summer LAP generation is projected to be between 86 percent and 104 percent of average at this time.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 16,195 kAF, which is about 52 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (January 2015) were about 109 percent of average. Lake Powell elevation currently is about 3,593 feet, 107 feet from maximum reservoir level and about 103 feet from the minimum generation level. Based on the current forecast, the February 24- Month Study projects Lake Powell elevation will end the water year near 3,597 feet with approximately 11.469 MAF in storage (47 percent capacity). A lack of storms in the Colorado River Basin in January 2015 has lowered the inflow estimates for the April-July runoff period to about 70 percent of average.

Based on the most probable inflow forecast, estimated SLCA/IP net generation for FY 2015 is 4,966 GWh as compared to 5,571 GWh based on the long-term historical average generation.

Purchase power expenses for firming during FY 2015 are estimated at $18.5 million as compared to about $21.5 million based on long-term average historical releases. Purchase power availability in the region is good and prices are low for this time of year. Firming purchases for the last month have been averaging in the upper $20s to low $30s off-peak and mid to high $30s on-peak.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 13.011 MAF (12.774 MAF December 2014), 20.838 MAF (65-Year Historical Average).

The Lake Mead end of January 2015 elevation was 1,088.51 feet (0.72 feet higher than end of December 2014 elevation ), or about 131.13 feet below full storage elevation of 1,219.64 feet and 38.51 feet above the minimum generation elevation for Hoover of 1,050 feet.

Lake Mead’s elevation is projected to peak at 1,089.25 feet in February of water year (WY) 2015 (19.5 feet below the WY 2014 peak elevation of 1,108.75 feet), and drop to a minimum elevation of 1,073.37 feet in June of WY 2015. This projected minimum elevation is below the 1,075 feet Shortage Condition elevation. However, this does not mean that Lake Mead would be operating under Shortage Conditions for WY 2015. Lake Mead is currently operating under Normal Conditions for WY 2015. Lake Mead’s elevation at the beginning of WY 2015 (October 1, 2014) was 25.4 feet lower than at the beginning of WY 2014 (October 1, 2013).

The projected 2015 April-July unregulated inflow into Lake Powell is 5.20 MAF or 73 percent of average (actual of 6.92 MAF or 97 percent of average for 2014).

Basin Snow Pack and Precipitation: DSW hydrology, or the Lower Colorado River Basin, is mostly dependent on the Colorado River Basin snow pack and precipitation above Lake Powell. The WY 2015 precipitation is currently 76 percent of average and the snowpack is 80 percent of average.

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for January 2015 was 72 kAF. The projected side inflow into Lake Mead for WY 2015 is 824 kAF which represents a 21.7 percent increase over last year’s actual of 677 kAF and 63 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2015 Generation: 5,157 GWh compared to 5,633 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2015 is 92 percent of the average historical generation.

Wholesale Power Market Conditions: The December market prices in the Desert Southwest averaged about $26/MWh firm on-peak, $24/MWh firm off-peak compared to $31/MWh firm on-peak, $24/MWh firm off-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 4.605 MAF, compared to 4.148 MAF last year. Accumulated inflow for the water year-to-date is 167 percent of the 15-year average for Trinity, 111 percent for Shasta, 72 percent for Folsom, and 71 percent for New Melones. None of the reservoirs is in flood control operations at this time.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak on April 1. Therefore, snow water equivalents are reported as a percentage of this average. As of February 10, the North was at 18 percent, the Central was at 21 percent, and the South was at 18 percent of this average. The recent precipitation was mainly rain rather than snow, which is unfortunate since snowpack is storage. The Sacramento River Index forecast of water supply based upon

February 1 conditions is “critical” for the 90 percent exceedance, but “below normal” for the 50 percent case.

Hydro Conditions and Purchase Power Monthly Outlook March 2015

Western Summary

• The most probable forecast of net generation for fiscal year (FY) 2015 is 25,134 gigawatt- hours (GWh) or 95 percent of average. October through February generation was 95 percent of average. • The lower level forecast of generation for FY 2015 is 23,915 GWh or 91 percent of average. • The amount of power purchased for FY 2015 is expected to range between 2,131 and 2,644 GWh. • The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to range between $49/megawatt-hour (MWh) and $53/MWh for FY 2015 – compared to an actual average price of $50/MWh for FY 2014. • Purchase power expenses for FY 2015 are forecast to range between $114 and $130 million – compared to actual purchase power expenses of $226 million in FY 2014. • October through February purchases totaled $74 million – compared to $142 million for the same timeframe the year before.

Cumulative of Actual Purchase Power Expenses - FY 15 $150

Most $125 Probable/Actual Dry

$100

$75

Millions of Dollars $50

$25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month

Upper Great Plains Region

Corps of Engineers Report: Runoff for February was 2 million acre-feet (MAF) or 186 percent of normal. Temperatures were warmer than normal in Montana and Wyoming which caused some early melting of the accumulated snowpack. The March 2015 forecast runoff is 24.6 MAF, slightly below the average of 25.2 MAF. System storage increased slightly to 57.1 MAF, above February's 56.5 MAF. This is still slightly above the Base Flood Control level of 56.1 MAF. The Corps is forecasting a full navigation season with no spring pulse this year.

Snowpack: As of March 1, 2015, the snowpack at Yellowtail was 96 percent of normal while Canyon Ferry dropped to 88 percent. The main stem snowpack dropped to 88 percent above Fort Peck and 98 percent on the reach from Fort Peck to Garrison. Warm temperatures in early March melted most of the snow that had accumulated on the plains.

Canyon Ferry: As of March 8, 2015, reservoir storage at Canyon Ferry was 1,515.0 thousand acre-feet (kAF) and the active conservation pool was 80.1 percent full. The anticipated inflow for the April-July spring runoff period is forecast to be 1530.2 kAF or 90 percent of the 30-year average.

Yellowtail: As of March 8, 2015, reservoir storage at Yellowtail was 897.3 kAF and the active conservation pool was 87.9 percent full. Streamflows into Bighorn Lake during January were 159 percent of average. On March 1, the Natural Resources Conservation Service measured the snow water content of the mountain snowpack in the Bighorn Basin at 94 percent of average. Based on the March 1 water supply forecast and the planned releases out of the Boysen and Buffalo Bill Reservoirs, the April-July runoff into Bighorn Lake is expected to equal 1,065.6 kAF or 99 percent of average.

Generation: The six main stem power plants generated 637 GWh of electricity in February.

Purchase Power: UGPR is entering the spring months of the generating season and with loads decreasing, prices are expected to be in the low $20s for off-peak power and the mid $30s for on-peak power.

Rocky Mountain Region

Moderate drought conditions have returned to the Colorado River headwaters above Lake Powell and the extreme upper headwaters above Kremmling that supply the Colorado-Big

Thompson Project (CBT) are trending toward drought. The snowpack was well below average in the North Platte Basin above Seminoe Dam, near average in the Upper Colorado River headwaters above Kremmling, and above average in the Bighorn Basin above Yellowtail Dam at the beginning of the month. Reservoir inflows have been well above average since September due to good precipitation this fall and winter. The overall LAP reservoir storage at the end of February was above average with gains in all three basins since the end of last February. The latest National Weather Service forecast indicates April through June temperatures will more likely be above average in western Wyoming and just as likely to be above as below average in eastern Wyoming and Colorado. The same forecast indicates precipitation will more likely be above average in southern Wyoming and Colorado and just as likely to be above as below average in northern Wyoming. Reclamation is forecasting reservoir inflows to be well below average in the North Platte Basin, near average in the Bighorn Basin, and above average for the CBT.

LAP Water Conditions At-A-Glance

CBT 807.9 639.9 126% 387.3 390.1 99% 637.0 599.0 106%

North Platte 1,670.3 1,420.0 118% 296.0 381.0 78% 400.0 694.0 58%

Bighorn 2,034.8 1,737.3 117% 311.1 294.0 106% 1,315.0 1,321.1 100%

TOTAL 4,513.0 3,797.2 119% 994.4 1,065.1 93% 2,352.0 2,614.1 90%

Net At Plant Generation Projections (GWh)

Winter 14-15 534.4 718.0 74% 521.7 718.0 73% 536.6 718.0 75%

Summer 15 1,374.4 1,217.8 113% 1,113.6 1,217.8 91% 1,479.0 1,217.8 121%

TOTAL 2015 1,908.8 1,935.8 99% 1,635.3 1,935.8 84% 2,015.6 1,935.8 104%

The winter season generation is expected to be about 74 percent of average and seasonal energy purchases have been arranged to support LAP firm electric service commitments. CBT Adams Tunnel imports from the west slope and associated generation will be well below normal this winter because the east slope storage space is limited after low water demands last year. Winter reservoir releases and associated generation in the North Platte Basin will be typical of recent operations and the release from Bighorn Lake via the Yellowtail power plant is above average under the latest Bighorn Lake operating criteria. The upcoming summer LAP generation is projected to be between 84 percent and 104 percent of average at this time.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 16.043 MAF, which is about 52 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (February 2015) were about 114 percent of average. Lake Powell elevation currently is about 3,592 feet, 108 feet from maximum reservoir level, and about 102 feet from the minimum generation level. Based on the current forecast, the March 24-Month study projects Lake Powell elevation will end the water year near 3,596 feet with approximately 11.376 MAF in storage (47 percent capacity). A lack of storms in the Colorado River Basin thus far this year has lowered the inflow estimates for the April to July runoff period to about 70 percent of average.

Based on the most probable inflow forecast, estimated SLCA/IP net generation for FY 2015 is 4,993 GWh as compared to 5,571 GWh based on the long-term historical average generation.

Purchase power availability in the region is good and prices are low for this time of year. Firming purchases for the last month have been averaging in the mid to upper $20s off-peak and mid $30s on-peak.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 12.993 MAF (13.011 MAF January 2015), 20.864 MAF (65-Year Historical Average).

The Lake Mead end of February 2015 elevation was 1,088.98 feet (0.47 feet higher than end of January 2015 elevation), or about 130.66 feet below full storage elevation of 1,219.64 feet and 38.98 feet above the minimum generation elevation for Hoover of 1,050 feet.

Lake Mead’s elevation peaked at 1,088.98 feet in February of water year (WY) 2015 (19.8 feet below the WY 2014 peak elevation of 1108.75 feet), and is projected to drop to a minimum elevation of 1,073.54 feet in July of WY 2015. This projected minimum elevation is below the 1,075 feet Shortage Criteria elevation. However, this does not mean that Lake Mead would be operating under Shortage Conditions for WY 2015. Lake Mead is currently operating under Normal Conditions for WY 2015. Lake Mead’s elevation at the beginning of WY 2015 (October 1, 2014) was 25.4 feet lower than at the beginning of WY 2014 (October 1, 2013). There is now a 20 percent probability that Lake Mead will be operating under the Shortage Criteria for WY 2016.

above 3,575 feet and the Lake Mead elevation will be below 1,075 feet on September 30, 2015. The projected 2015 April-July unregulated inflow into Lake Powell is 4.9 MAF or 68 percent of average (actual of 6.92 MAF or 97 percent of average for 2014).

Basin Snow Pack and Precipitation: DSW hydrology, or the Lower Colorado River Basin, is mostly dependent on the Colorado River Basin snow pack and precipitation above Lake Powell. The WY 2015 precipitation is currently 78 percent of average and the snowpack is 76 percent of average.

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for February 2015 was 89 kAF. The projected side inflow into Lake Mead for WY 2015 is 847 kAF which represents a 25.1 percent increase over last year’s actual of 677 kAF, and represents 65 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2015 Generation: 5,101 GWh compared to 5,632 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2015 is 91 percent of the average historical generation.

Wholesale Power Market Conditions: The February market prices in the Desert Southwest averaged about $21/MWh firm off-peak, $24/MWh firm on-peak compared to $24/MWh firm off-peak, $26/MWh firm on-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 5.005 MAF, compared to 4.823 MAF last year. Accumulated inflow for the water year-to-date is 147 percent of the 15-year average for Trinity, 93 percent for Shasta, 60 percent for both Folsom and New Melones. None of the reservoirs is in flood control operations at this time.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. This water year started out with October recorded precipitation totaling 2.74 inches, which is 90 percent of the monthly average. November recorded precipitation totaled 4.35 inches, which is 70 percent of average. December recorded precipitation totaled 15.85 inches or 179 percent of average. January recorded precipitation totaled 0.28 inches or 3 percent of average. It was one of the fifth driest on record. February ended at 7.50 inches or 92 percent of its average. As of the 19th, March is at 0.51 inches or 7 percent of its average. The cumulative total at this time is 31.08 inches or 62 percent of the annual average. December and January are the months with the highest average, with February very close. Hopes for a “miracle March” have dwindled.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak April 1. Therefore, snow water

equivalents are reported as a percentage of this average. As of March 17, the North is at 3 percent, the Central is at 4 percent, and the South is at 4 percent of this average. The Sacramento River Index forecast of water supply based upon March 1 conditions is “critical” for both the 90 percent and the 50 percent exceedence cases.

Hydro Conditions and Purchase Power Monthly Outlook April 2015

Western Summary

• The most probable forecast of net generation for fiscal year (FY) 2015 is 24,620 gigawatt- hours (GWh) or 93 percent of average. October through March generation was 95 percent of average. • The lower level forecast of generation for FY 2015 is 23,481 GWh or 89 percent of average. • The amount of power purchased for FY 2015 is expected to range between 2,345 and 2,799 GWh. • The average price for purchase power across all hydro projects and off-peak and on-peak periods is expected to range between $50/megawatt-hour (MWh) and $54/MWh for FY 2015 – compared to an actual average price of $50/MWh for FY 2014. • Purchase power expenses for FY 2015 are forecast to range between $127 and $140 million – compared to actual purchase power expenses of $226 million in FY 2014. • October through March purchases totaled $95 million – compared to $162 million for the same timeframe the year before.

Cumulative of Actual Purchase Power Expenses - FY 15 $150

Most $125 Probable/Actual Dry

$100

$75 Millions of Dollars

$50

$25

$0 Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Month

Upper Great Plains Region

Corps of Engineers Report: Runoff for March was 2.2 million acre-feet (MAF) or 74 percent of normal. Temperatures were near normal in Montana and Wyoming but the lack of snow and rain persisted. The April forecast runoff for 2015 is 20.3 MAF or 80 percent of normal. This is well below the average of 25.2 MAF. System storage increased slightly to 57.4 MAF above March's 57 .1 MAF. This is still slightly above the Base Flood Control level of 56.1 MAF.

Snowpack: The lack of any measurable spring snow has caused a significant drop in snowpack from last month. As of April 1, 2015, the snowpack at Yellowtail was 76 percent of normal while Canyon Ferry dropped to 75 percent. The main stem snowpack dropped to 66 percent above Fort Peck and 74 percent on the reach from Fort Peck to Garrison.

Canyon Ferry: As of April 12, 2015, reservoir storage at Canyon Ferry was 1,546.6 thousand acre-feet (kAF) and the active conservation pool was 81.7 percent full. The anticipated inflow for the April-July spring runoff period is forecast to be 1,107.5 kAF or 65 percent of the 30-year average.

Yellowtail: As of April 12, 2015, reservoir storage at Yellowtail was 853.4 kAF and the active conservation pool was 83.6 percent full. Streamflows into Bighorn Lake during March were 110 percent of average. On April 1, the Natural Resources Conservation Service measured the snow water content of the mountain snowpack in the Bighorn Basin at 75 percent of average. Based on the April 1 water supply forecast and the planned releases out of the Boysen and Buffalo Bill Reservoirs, the April-July runoff into Bighorn Lake is expected to equal 675.5 kAF or 62 percent of average.

Generation: The six main stem power plants generated 745 GWh of electricity in March.

Purchase Power: UGPR is in the spring months of the generating season and with loads decreasing, prices are expected to be in the low $20s for off-peak power and the low $30s for on-peak power.

Rocky Mountain Region

Moderate to severe drought conditions have returned to the Colorado River headwaters above Lake Powell with the extreme upper headwaters above Kremmling that supply the Colorado-Big Thompson Project (CBT) less impacted. The snowpack is now well below average in all three

basins. Reservoir inflows were well above average all winter due to good fall precipitation and then some melting of lower elevation snow during warmer periods. The overall LAP reservoir storage at the end of March was still above average with gains in all three basins since the end of last March. The latest National Weather Service forecast calls for temperatures in the May to July period to be just as likely above as below normal in Colorado and Eastern Wyoming and more likely to be above normal in Western Wyoming. Precipitation is more likely to be above normal throughout the LAP area. Reclamation is forecasting spring reservoir inflows to be below average for the CBT and well below average in the North Platte and Bighorn basins.

LAP Water Conditions At-A-Glance

CBT 808.6 629.3 128% 375.4 468.9 80% 532.6 599.0 89%

North Platte 1,746.0 1,478.2 118% 342.2 499.3 69% 250.0 694.0 36%

Bighorn 2,004.4 1,723.2 116% 299.2 373.5 80% 827.0 1,321.1 63%

TOTAL 4,559.0 3,830.7 119% 1,016.8 1,341.7 76% 1,609.6 2,614.1 62%

Net At Plant Generation Projections (GWh)

Winter 14-15 520.3 718.0 72% 520.3 718.0 72% 520.3 718.0 72%

Summer 15 1,201.1 1,217.8 99% 1,001.9 1,217.8 82% 1,351.2 1,217.8 111%

TOTAL 2015 1,721.4 1,935.8 89% 1,522.2 1,935.8 79% 1,871.5 1,935.8 97%

The winter season generation was 72 percent of average and about 485 GWh of energy was purchased to support LAP firm electric service commitments. CBT Adams Tunnel imports from the west slope and associated generation were well below normal over the winter because the east slope storage space was limited after low water demands last year. Winter reservoir releases and associated generation in the North Platte Basin were typical of recent operations and the release from Bighorn Lake via the Yellowtail power plant was above average under the latest Bighorn Lake operating criteria. The upcoming summer LAP generation is projected to be between 79 percent and 97 percent of average at this time with some surplus generation expected only in the heaviest snow melt runoff months of May and June. No surplus LAP firm energy will be offered to firm electric service customers this spring and summer.

Colorado River Storage Project Management Center

The total storage volume for the CRSP main stem reservoirs is 16.037 MAF, which is about 52 percent of the total main stem reservoir storage capacity. Main stem reservoir inflows for the most recent historical month (March 2015) were about 89 percent of average. Lake Powell elevation currently is about 3,591 feet, 109 feet from maximum reservoir level and about 101 feet from the minimum generation level. Based on the current forecast, the April 24-Month study projects Lake Powell elevation will end the water year near 3,583 feet with approximately 10.236 MAF in storage or 42 percent capacity. A lack of storms in the Colorado River Basin thus far this year has lowered the inflow estimates for the April to July runoff period to about 52 percent of average.

Based on the most probable inflow forecast, estimated SLCA/IP net generation for FY 2015 is 4,899 GWh as compared to 5,571 GWh based on the long-term historical average generation.

Purchase power expenses for firming during the fiscal year 2015 are estimated at $22.1 million as compared to about $21.7 million based on long–term average historical releases. Purchase power availability in the region is good and prices are low for this time of year. Firming purchases for the last month have been averaging in the mid to upper $20s off-peak and mid $30s on-peak.

Desert Southwest Region

Current Aggregate Storage (Mead, Mohave & Havasu): 12.690 MAF (12.993 MAF February 2015), 20.663 MAF (65-Year Historical Average).

The Lake Mead end of March 2015 elevation was 1,084.87 feet (4.11 feet lower than end of February 2015 elevation ), or about 134.77 feet below full storage elevation of 1,219.64 feet and 34.87 feet above the minimum generation elevation for Hoover of 1,050 feet.

Lake Mead’s elevation peaked at 1,088.98 feet in February of water year (WY) 2015 (19.8 feet below the WY 2014 peak elevation of 1108.75 feet), and is projected to drop to a minimum elevation of 1,073.03 feet in June of WY 2015. This projected minimum elevation is below the 1,075 feet Shortage Criteria elevation. However, this does not mean that Lake Mead would be operating under Shortage Conditions for WY 2015. Lake Mead is currently operating under Normal Conditions for WY 2015. Lake Mead’s elevation at the beginning of WY 2015 (October 1, 2014) was 25.4 feet lower than at the beginning of WY 2014 (October 1, 2013). There is now a 20 percent probability that Lake Mead will be operating under the Shortage Criteria for WY 2016.

The Lake Powell operational tier for WY 2015 is currently the Upper Elevation Balancing Tier. Total releases from Lake Powell are projected to average about 9.0 MAF for WY 2015 (actual of

7.48 MAF for WY 2014). These releases above the normal 8.23 MAF are characterized as “balancing releases” due to the current projection that the Lake Powell elevation will be at or above 3,575 feet and the Lake Mead elevation will be below 1,075 feet on September 30, 2015. The projected 2015 April-July unregulated inflow into Lake Powell is 3.75 MAF or 52 percent of average (actual of 6.92 MAF or 97 percent of average for 2014).

Basin Snow Pack and Precipitation: DSW hydrology, or the Lower Colorado River Basin, is mostly dependent on the Colorado River Basin snow pack and precipitation above Lake Powell. The WY 2015 precipitation is currently 75 percent of average and the snowpack is 56 percent of median.

Lower Basin Runoff: The lower basin tributary inflow into Lake Mead for March 2015 was 57 kAF. The projected side inflow into Lake Mead for WY 2015 is 844 kAF which represents a 24.7 percent increase over last year’s actual of 677 kAF, and represents 65 percent of the normal annual side inflow of 1.3 MAF.

Forecasted WY 2015 Generation: 5,088 GWh compared to 5,632 GWh (Historical Average). The projected Hoover and Parker-Davis generation for WY 2015 is 90 percent of the average historical generation.

Wholesale Power Market Conditions: The March market prices in the Desert Southwest averaged about $22/MWh firm off-peak, $25/MWh firm on-peak compared to $21/MWh firm off-peak, $24/MWh firm on-peak for the previous month.

Sierra Nevada Region

The total storage of the four major CVP reservoirs is 4.951 MAF, compared to 5.178 MAF last year. Accumulated inflow for the water year-to-date is 110 percent of the 15-year average for Trinity, 79 percent for Shasta, and 46 percent for both Folsom and New Melones. None of the reservoirs is in flood control operations at this time.

The Northern Sierra Eight Station index averages slightly more than 50 inches of precipitation per water year. This water year started out with October recorded precipitation totaling 2.74 inches, which is 90 percent of the monthly average. November recorded precipitation totaled 4.35 inches, which is 70 percent of average. December recorded precipitation totaled 15.85 inches or 179 percent of average. January recorded precipitation totaled 0.28 inches or 3 percent of average. It was one of the fifth driest on record. February ended at 7.50 inches or 92 percent of its average. March ended at 1.08 inches or 16 percent of average. It was one fifth driest on record. As of April 27, the month was at 2.37 inches or 61 percent of average. The cumulative total at this time is 33.02 inches or 68 percent of the annual average. December and January are the months with the highest average, with February very close.

Water year type forecasting begins in December, but snow surveying doesn’t begin until January. The snowpack is assumed to reach its peak on April 1. Therefore, snow water equivalents are reported as a percentage of this average. As of April 27, the North is at 1 percent, the Central is at 5 percent, and the South is at 3 percent of this average. The Sacramento River Index forecast of water supply based upon April 1 conditions is “critical” for both the 90 percent and the 50 percent exceedence cases.

Western Area Power Administration Hydro Conditions and Purchase Power Report May 2015

Western-Wide

Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Dry Probable Actual Oct 14 1,826,532 1,977,668 1,886,361 1,959,502 $10,380,564 $6,775,943 $8,098,109 Nov 14 1,678,876 1,878,130 1,730,985 1,779,466 $12,052,771 $8,753,145 $11,491,469 Dec 14 1,400,852 1,466,433 1,741,762 1,495,299 $27,892,938 $22,193,540 $14,331,279 Jan 15 1,582,275 1,685,555 1,858,893 1,772,024 $21,978,980 $17,467,062 $15,702,191 Feb 15 1,394,573 1,413,966 1,708,390 1,455,474 $19,588,891 $18,262,214 $13,244,067 Mar 15 1,864,152 1,820,595 1,906,554 1,867,882 $11,564,400 $12,466,384 $8,028,129 Apr 15 2,110,829 2,225,796 2,143,336 2,027,035 $5,743,735 $3,508,301 $4,744,616 May 15 Jun 15 Jul 15 Aug 15 Sep 15 Total 11,858,089 12,468,143 12,976,280 12,356,681 $109,202,279 $89,426,590 $75,639,861 Actual generation as a percentage of average: 95%

Western Area Power Administration (Western) generated a total of 12,357 gigawatt-hours during October through April of fiscal year 2015, or 95 percent of the average. Total purchase power expenses for the same period were $75,639,861.

The following pages indicate Western’s Regional snowpack, lake/reservoir inflow and content, generation, and purchase power expenses, among other things. Snowpack is reported as snow water equivalent, which is the depth of water that theoretically would result if the entire snowpack is melted instantaneously.

Colorado River Storage Project

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 0.20 0.30 408.80 636.00 15.01 12.29 248,012 338,348 382,430 357,465 $6,704,081 $2,989,589 $3,353,763 Nov 14 1.80 3.91 510.71 420.00 14.91 11.93 230,952 308,547 388,155 337,735 $7,549,826 $4,237,967 $5,504,854 Dec 14 5.10 7.80 474.22 465.00 14.86 11.54 270,310 408,665 437,962 473,595 $7,692,571 $1,952,432 $1,405,094 Jan 15 8.70 9.40 363.30 449.00 14.98 11.15 355,138 405,825 457,394 474,003 $4,412,679 $2,266,923 $1,523,337 Feb 15 12.20 11.70 362.24 464.00 15.99 11.02 265,647 301,110 390,580 322,910 $5,024,221 $3,790,958 $3,744,097 Mar 15 15.80 12.60 391.67 543.00 16.77 10.91 272,465 304,805 390,170 353,115 $5,517,603 $4,342,357 $3,876,509 Apr 15 19.60 10.50 665.00 539.00 16.74 10.84 250,695 328,527 397,861 328,527 $3,468,325 $1,662,291 $1,968,191 May 15 Jun 15 Jul 15 Aug 15 Sep 15 Total 1,893,220 2,395,827 2,844,551 2,647,351 $40,369,305 $21,242,516 $21,375,845 Actual generation as a percentage of average: 93%

Lake/Reservoir Levels Lake Powell’s elevation was 3,592 feet at the end of April, about 108 feet from maximum reservoir level and about 102 feet from the minimum generation level. Based on the current forecast, Lake Powell’s elevation will end water year (WY) 2015 near 3,578 feet.

Weather and Other Conditions A lack of storms in the Colorado River Basin has lowered the inflow estimates for the April-July runoff period to about 52 percent of average, although a wet May has improved prospects.

Desert Southwest Region

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 0.20 0.30 58.00 68.00 20.53 12.27 294,250 294,250 380,500 272,691 $0 $109,870 $106,819 Nov 14 1.80 3.91 54.00 44.00 20.57 12.41 325,000 372,000 363,500 357,310 $10,239 $22,472 $23,998 Dec 14 5.10 7.80 75.00 56.00 20.69 12.77 286,750 290,400 373,900 251,260 $294,966 $120 $534,300 Jan 15 8.70 9.40 93.00 72.00 20.84 13.01 411,100 411,100 398,400 428,462 $0 $0 $39,296 Feb 15 12.20 11.70 110.00 89.00 20.86 12.99 352,400 319,250 391,500 335,602 $0 $0 $8,661 Mar 15 15.80 12.60 105.00 57.00 20.66 12.69 543,600 526,100 531,400 560,224 $57,626 $94,756 $166,762 Apr 15 19.60 10.50 85.00 26.00 20.49 12.20 601,550 601,750 571,800 588,889 $0 $0 $7,714 May 15 Jun 15 Jul 15 Aug 15 Sep 15 Total 2,814,650 2,814,850 3,011,000 2,794,438 $362,831 $227,218 $887,550 Actual generation as a percentage of average: 93%

Lake/Reservoir Levels Lake Mead’s elevation was 1,079 feet at the end of April, about 141 feet below full storage level and about 29 feet from the minimum generation level. Lake Mead’s elevation is projected to drop to a minimum elevation of 1,073 feet in June of WY 2015.

Weather and Other Conditions The Desert Southwest Region’s hydrology is mostly dependent on the Colorado River Basin snowpack and precipitation above Lake Powell. Based on current and projected conditions, there is now a 33 percent probability that Lake Mead will be operating under the Shortage Criteria for WY 2016.

Rocky Mountain Region

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 139.20 200.80 3.84 4.47 99,021 102,458 83,694 91,560 $2,257,085 $2,257,085 $2,257,085 Nov 14 121.40 129.20 3.87 4.47 60,006 60,146 82,089 55,233 $3,178,702 $3,178,702 $3,178,702 Dec 14 97.90 139.40 3.83 4.47 89,969 90,045 103,710 88,510 $2,294,873 $2,294,873 $2,294,873 Jan 15 407.20 427.80 96.20 129.40 3.80 4.47 106,726 106,906 113,597 102,961 $2,614,295 $2,606,695 $2,203,620 Feb 15 808.10 739.20 95.00 128.60 3.80 4.51 85,735 86,024 102,200 79,516 $2,054,163 $2,042,763 $1,780,322 Mar 15 1,065.10 994.40 158.40 199.30 3.83 4.56 96,042 108,706 120,988 103,860 $2,128,149 $1,645,549 $1,726,554 Apr 15 1,341.70 1,016.80 253.10 257.80 3.85 4.60 125,443 138,545 140,995 128,526 $1,707,570 $1,278,170 $1,485,335 May 15 Jun 15 Jul 15 Aug 15 Sep 15 Total 662,941 692,828 747,273 650,166 $16,234,838 $15,303,838 $14,926,491 Actual generation as a percentage of average: 87%

Lake/Reservoir Content The overall reservoir content at the end of April was 119 percent of average.

Weather and Other Conditions The Bureau of Reclamation is forecasting spring reservoir inflows to be below average for the Colorado-Big Thompson Project and well below average in the Bighorn and North Platte basins.

Note: Rocky Mountain Region (RMR)-related snowpack either is not measured or is relatively insignificant during the months of October through December. Consequently, RMR does not project purchase power expenses for these months.

Sierra Nevada Region

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 329.00 263.00 5.61 2.49 161,181 106,181 163,000 115,957 $1,419,398 $1,419,398 $2,380,441 Nov 14 5.26 1.00 404.00 281.00 5.56 2.40 99,417 69,417 104,000 75,640 $1,314,004 $1,314,004 $2,396,084 Dec 14 4.94 5.00 1,014.00 1,450.00 6.06 3.66 69,042 0 143,000 13,282 $1,252,191 $1,252,191 $2,458,218 Jan 15 5.80 4.00 954.00 508.00 6.39 3.89 0 0 163,000 23,872 $1,508,460 $1,508,460 $2,077,046 Feb 15 9.00 5.00 997.00 1,232.00 6.92 4.93 0 14,968 195,000 29,080 $1,363,440 $1,363,440 $1,800,319 Mar 15 15.00 2.00 1,330.00 412.00 7.56 5.01 115,340 100,340 207,000 45,340 $1,506,498 $1,506,498 $1,974,521 Apr 15 10.00 1.00 1,245.00 341.00 7.95 4.91 171,316 231,316 288,000 126,768 $567,840 $567,840 $1,283,377 May 15 Jun 15 Jul 15 Aug 15 Sep 15 Total 616,296 522,222 1,263,000 429,939 $8,931,832 $8,931,832 $14,370,007 Actual generation as a percentage of average: 34%

Lake/Reservoir Content The overall reservoir content at the end of April was 62 percent of average.

Weather and Other Conditions Accumulated inflow for the WY-to-date is 88 percent of the 15-year average for Trinity, 74 percent for Shasta, and 40 percent for both Folsom and New Melones.

Note: Sierra Nevada Region (SNR)-related snowpack is not measured for the month of October. In addition, SNR’s average projection of generation is taken from the latest modeling using the update to its customers’ “Green Book,” and SNR does not project purchase power expenses for dry conditions.

Upper Great Plains Region

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 0.09 0.00 8,092.00 10,685.90 55.94 59.74 1,024,068 1,136,432 876,737 1,121,829 $0 $0 $0 Nov 14 1.20 0.30 7,411.00 8,616.60 54.83 58.09 963,501 1,068,021 793,241 953,548 $0 $0 $387,831 Dec 14 3.80 3.90 6,468.00 6,229.90 54.23 57.97 684,781 677,324 683,190 668,651 $16,358,337 $16,693,924 $7,638,795 Jan 15 7.10 7.30 6,658.00 6,786.10 53.94 58.03 709,312 761,724 726,502 742,726 $13,443,547 $11,084,984 $9,858,892 Feb 15 10.30 9.70 6,291.00 6,679.80 54.25 58.60 690,792 692,614 629,110 688,365 $11,147,066 $11,065,054 $5,910,668 Mar 15 12.90 11.50 8,226.00 7,837.90 56.02 59.12 836,705 780,645 656,996 805,343 $2,354,524 $4,877,224 $283,782 Apr 15 15.80 10.70 8,061.00 9,554.70 56.91 55.80 961,825 925,659 744,680 854,325 $0 $0 $0 May 15 Jun 15 Jul 15 Aug 15 Sep 15 Total 5,870,982 6,042,417 5,110,456 5,834,787 $43,303,473 $43,721,186 $24,079,968 Actual generation as a percentage of average: 114%

Lake/Reservoir Content As of May 11, 2015, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 84 and 83 percent full, respectively.

Weather and Other Conditions El Nino conditions continue to cause dry weather in the upper plains which has put those states into moderate drought conditions. The spring runoff at both Canyon Ferry and Yellowtail is in full swing and snowpack is melting rapidly.

Note: The Upper Great Plains Region reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation.

Western Area Power Administration Hydro Conditions and Purchase Power Report June 2015

Western-Wide

Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Dry Probable Actual Oct 14 1,826,532 1,977,668 1,886,361 1,959,502 $10,380,564 $6,775,943 $8,098,109 Nov 14 1,678,876 1,878,130 1,730,985 1,779,466 $12,052,771 $8,753,145 $11,491,469 Dec 14 1,400,852 1,466,433 1,741,762 1,495,299 $27,892,938 $22,193,540 $14,331,279 Jan 15 1,582,275 1,685,555 1,858,893 1,772,024 $21,978,980 $17,467,062 $15,702,191 Feb 15 1,394,573 1,413,966 1,708,390 1,455,474 $19,588,891 $18,262,214 $13,244,067 Mar 15 1,864,152 1,820,595 1,906,554 1,867,882 $11,564,400 $12,466,384 $8,028,129 Apr 15 2,110,829 2,225,796 2,143,336 2,025,729 $5,743,735 $3,508,301 $4,723,440 May 15 2,236,720 2,352,849 2,616,795 2,107,931 $2,800,825 $1,217,038 $2,112,055 Jun 15 Jul 15 Aug 15 Sep 15 Total 14,094,809 14,820,992 15,593,075 14,463,307 $112,003,104 $90,643,628 $77,730,740 Actual generation as a percentage of average: 93%

Western Area Power Administration (Western) generated a total of 14,463 gigawatt-hours during October through May of fiscal year 2015, or 93 percent of the average. Total purchase power expenses for the same period were $77,730,740.

Colorado River Storage Project

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 0.20 0.30 408.80 636.00 15.01 12.29 248,012 338,348 382,430 357,465 $6,704,081 $2,989,589 $3,353,763 Nov 14 1.80 3.90 510.71 420.00 14.91 11.93 230,952 308,547 388,155 337,735 $7,549,826 $4,237,967 $5,504,854 Dec 14 5.10 7.80 474.22 465.00 14.86 11.54 270,310 408,665 437,962 473,595 $7,692,571 $1,952,432 $1,405,094 Jan 15 8.70 9.40 363.30 449.00 14.98 11.15 355,138 405,825 457,394 474,003 $4,412,679 $2,266,923 $1,523,337 Feb 15 12.20 11.70 362.24 464.00 15.99 11.02 265,647 301,110 390,580 322,910 $5,024,221 $3,790,958 $3,744,097 Mar 15 15.80 12.60 391.67 543.00 16.77 10.91 272,465 304,805 390,170 353,115 $5,517,603 $4,342,357 $3,876,509 Apr 15 19.60 10.50 665.00 539.00 16.74 10.84 250,695 328,527 397,861 332,925 $3,468,325 $1,662,291 $1,968,191 May 15 19.90 8.30 1,059.34 1,431.00 16.30 11.49 320,070 383,522 501,886 383,522 $2,044,585 $460,798 $172,668 Jun 15 Jul 15 Aug 15 Sep 15 Total 2,213,290 2,779,348 3,346,438 3,035,271 $42,413,890 $21,703,314 $21,548,512 Actual generation as a percentage of average: 91%

Lake/Reservoir Levels Lake Powell’s elevation was 3,597 feet at the end of May, about 103 feet from maximum reservoir level and about 107 feet from the minimum generation level. Based on the current forecast, Lake Powell’s elevation will end water year (WY) 2015 near 3,596 feet with approximately 11.34 million acre-feet in storage or 47 percent of capacity.

Weather and Other Conditions A generally dry winter in the Colorado River Basin has lowered the inflow estimates, although a wet May has improved prospects to about 70 percent of average April through July runoff.

Desert Southwest Region

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 0.20 0.30 58.00 68.00 20.53 12.27 294,250 294,250 380,500 272,691 $0 $109,870 $106,819 Nov 14 1.80 3.90 54.00 44.00 20.57 12.41 325,000 372,000 363,500 357,310 $10,239 $22,472 $23,998 Dec 14 5.10 7.80 75.00 56.00 20.69 12.77 286,750 290,400 373,900 251,260 $294,966 $120 $534,300 Jan 15 8.70 9.40 93.00 72.00 20.84 13.01 411,100 411,100 398,400 428,462 $0 $0 $39,296 Feb 15 12.20 11.70 110.00 89.00 20.86 12.99 352,400 319,250 391,500 335,602 $0 $0 $8,661 Mar 15 15.80 12.60 105.00 57.00 20.66 12.69 543,600 526,100 531,400 560,224 $57,626 $94,756 $166,762 Apr 15 19.60 10.50 85.00 26.00 20.49 12.20 601,550 601,750 571,800 583,186 $0 $0 $7,714 May 15 19.90 8.30 60.00 26.00 20.61 12.03 555,600 530,800 573,200 466,936 $0 $0 $330,256 Jun 15 Jul 15 Aug 15 Sep 15 Total 3,370,250 3,345,650 3,584,200 3,255,671 $362,831 $227,218 $1,217,806 Actual generation as a percentage of average: 91%

Lake/Reservoir Levels Lake Mead’s elevation was 1,077 feet at the end of May, about 143 feet below full storage level and about 27 feet from the minimum generation level.

Rocky Mountain Region

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 139.20 200.80 3.84 4.47 99,021 102,458 83,694 91,560 $2,257,085 $2,257,085 $2,257,085 Nov 14 121.40 129.20 3.87 4.47 60,006 60,146 82,089 55,233 $3,178,702 $3,178,702 $3,178,702 Dec 14 97.90 139.40 3.83 4.47 89,969 90,045 103,710 88,510 $2,294,873 $2,294,873 $2,294,873 Jan 15 407.20 427.80 96.20 129.40 3.80 4.47 106,726 106,906 113,597 102,961 $2,614,295 $2,606,695 $2,203,620 Feb 15 808.10 739.20 95.00 128.60 3.80 4.51 85,735 86,024 102,200 79,516 $2,054,163 $2,042,763 $1,780,322 Mar 15 1,065.10 994.40 158.40 199.30 3.83 4.56 96,042 108,706 120,988 103,860 $2,128,149 $1,645,549 $1,726,554 Apr 15 1,341.70 1,016.80 253.10 257.80 3.85 4.60 125,443 138,545 140,995 128,526 $1,707,570 $1,278,170 $1,464,159 May 15 301.50 355.20 694.10 758.20 4.18 5.21 190,340 198,107 198,626 166,491 $180,000 $180,000 $1,032,891 Jun 15 Jul 15 Aug 15 Sep 15 Total 853,281 890,935 945,899 816,657 $16,414,838 $15,483,838 $15,938,206 Actual generation as a percentage of average: 86%

Lake/Reservoir Content The overall reservoir content at the end of May was 125 percent of average.

Weather and Other Conditions The Bureau of Reclamation is now forecasting total spring reservoir inflows to be well below average in the North Platte Basin, above average for the Colorado-Big Thompson Project, and well above average in the Bighorn Basin.

Sierra Nevada Region

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 329.00 263.00 5.61 2.49 161,181 106,181 163,000 115,957 $1,419,398 $1,419,398 $2,380,441 Nov 14 5.26 1.00 404.00 281.00 5.56 2.40 99,417 69,417 104,000 75,640 $1,314,004 $1,314,004 $2,396,084 Dec 14 4.94 5.00 1,014.00 1,450.00 6.06 3.66 69,042 0 143,000 13,282 $1,252,191 $1,252,191 $2,458,218 Jan 15 5.80 4.00 954.00 508.00 6.39 3.89 0 0 163,000 23,872 $1,508,460 $1,508,460 $2,077,046 Feb 15 9.00 5.00 997.00 1,232.00 6.92 4.93 0 14,968 195,000 29,080 $1,363,440 $1,363,440 $1,800,319 Mar 15 15.00 2.00 1,330.00 412.00 7.56 5.01 115,340 100,340 207,000 45,340 $1,506,498 $1,506,498 $1,974,521 Apr 15 10.00 1.00 1,245.00 341.00 7.95 4.91 171,316 231,316 288,000 126,768 $567,840 $567,840 $1,283,377 May 15 0.00 1,203.00 301.00 7.91 4.42 246,135 336,135 442,000 230,955 $576,240 $576,240 $576,240 Jun 15 Jul 15 Aug 15 Sep 15 Total 862,431 858,357 1,705,000 660,894 $9,508,072 $9,508,072 $14,946,247 Actual generation as a percentage of average: 39%

Lake/Reservoir Content Accumulated inflow for the water year to date is 85 percent of average for Trinity, 73 percent for Shasta, 40 percent for Folsom, and 39 percent for New Melones. The overall reservoir content at the end of May was 56 percent of average.

Weather and Other Conditions As of May 8, the State of California water year type declaration was "critical" based upon the May 1 conditions 50 percent exceedence forecast. As of June 27, the cumulative precipitation was 35.98 inches or 72 percent of average for the Northern Sierra Eight Station Index.

Note: Sierra Nevada Region (SNR)-related snowpack is not measured for the month of October and no median was reported for May. SNR’s average projection of generation is taken from the latest modeling using the update to its customers’ “Green Book,” and SNR does not project purchase power expenses for dry conditions.

Upper Great Plains Region

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 0.09 0.00 8,092.00 10,685.90 55.94 59.74 1,024,068 1,136,432 876,737 1,121,829 $0 $0 $0 Nov 14 1.20 0.30 7,411.00 8,616.60 54.83 58.09 963,501 1,068,021 793,241 953,548 $0 $0 $387,831 Dec 14 3.80 3.90 6,468.00 6,229.90 54.23 57.97 684,781 677,324 683,190 668,651 $16,358,337 $16,693,924 $7,638,795 Jan 15 7.10 7.30 6,658.00 6,786.10 53.94 58.03 709,312 761,724 726,502 742,726 $13,443,547 $11,084,984 $9,858,892 Feb 15 10.30 9.70 6,291.00 6,679.80 54.25 58.60 690,792 692,614 629,110 688,365 $11,147,066 $11,065,054 $5,910,668 Mar 15 12.90 11.50 8,226.00 7,837.90 56.02 59.12 836,705 780,645 656,996 805,343 $2,354,524 $4,877,224 $283,782 Apr 15 15.80 10.70 8,061.00 9,554.70 56.91 55.89 961,825 925,659 744,680 854,325 $0 $0 $0 May 15 15.10 9.10 9,699.00 9,287.30 58.18 60.04 924,575 904,285 901,082 860,028 $0 $0 $0 Jun 15 Jul 15 Aug 15 Sep 15 Total 6,795,557 6,946,702 6,011,538 6,694,815 $43,303,473 $43,721,186 $24,079,968 Actual generation as a percentage of average: 111%

Lake/Reservoir Content As of June 15, 2015, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 99.5 percent and 100 percent full, respectively.

Weather and Other Conditions Spring rains arrived in May and partially moderated the drought conditions in the Dakotas.

Note: The Upper Great Plains Region reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation.

Western Area Power Administration Hydro Conditions and Purchase Power Report July 2015

Western-Wide

Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Dry Probable Actual Oct 14 1,826,532 1,977,668 1,886,361 1,959,502 $8,123,479 $4,518,858 $8,098,109 Nov 14 1,678,876 1,878,130 1,730,985 1,779,466 $8,874,069 $5,574,443 $11,491,469 Dec 14 1,400,852 1,466,433 1,741,762 1,495,299 $25,598,065 $19,898,668 $14,331,279 Jan 15 1,582,275 1,685,555 1,858,893 1,772,024 $21,978,980 $17,467,062 $15,702,191 Feb 15 1,394,573 1,413,966 1,708,390 1,455,474 $19,588,891 $18,262,214 $13,244,067 Mar 15 1,864,152 1,820,595 1,906,554 1,862,739 $11,564,400 $12,466,384 $8,028,129 Apr 15 2,110,829 2,225,796 2,143,336 2,025,729 $5,743,735 $3,508,301 $4,723,440 May 15 2,236,720 2,352,849 2,616,795 2,175,381 $2,800,825 $1,217,038 $2,677,808 Jun 15 2,262,474 2,393,989 2,699,771 2,215,962 $3,213,271 $2,965,229 $2,464,656 Jul 15 Aug 15 Sep 15 Total 16,357,283 17,214,981 18,292,846 16,741,576 $107,485,715 $85,878,197 $80,761,149 Actual generation as a percentage of average: 92%

Western Area Power Administration (Western) generated a total of 16,742 gigawatt-hours during October through June of fiscal year 2015, or 92 percent of the average. Total purchase power expenses for the same period were $80,761,149.

Colorado River Storage Project

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 0.20 0.30 408.80 636.00 15.01 12.29 248,012 338,348 382,430 357,465 $6,704,081 $2,989,589 $3,353,763 Nov 14 1.80 3.90 510.71 420.00 14.91 11.93 230,952 308,547 388,155 337,735 $7,549,826 $4,237,967 $5,504,854 Dec 14 5.10 7.80 474.22 465.00 14.86 11.54 270,310 408,665 437,962 473,595 $7,692,571 $1,952,432 $1,405,094 Jan 15 8.70 9.40 363.30 449.00 14.98 11.15 355,138 405,825 457,394 474,003 $4,412,679 $2,266,923 $1,523,337 Feb 15 12.20 11.70 362.24 464.00 15.99 11.02 265,647 301,110 390,580 322,910 $5,024,221 $3,790,958 $3,744,097 Mar 15 15.80 12.60 391.67 543.00 16.77 10.91 272,465 304,805 390,170 353,115 $5,517,603 $4,342,357 $3,876,509 Apr 15 19.60 10.50 665.00 539.00 16.74 10.84 250,695 328,527 397,861 332,925 $3,468,325 $1,662,291 $1,968,191 May 15 19.90 8.30 1,059.34 1,431.00 16.30 11.49 320,070 383,522 501,886 450,972 $2,044,585 $460,798 $172,668 Jun 15 9.00 0.30 2,339.33 2,570.00 16.00 13.09 337,289 400,213 585,467 400,213 $2,301,440 $603,666 $95,862 Jul 15 Aug 15 Sep 15 Total 2,550,579 3,179,561 3,931,905 3,502,934 $44,715,330 $22,306,980 $21,644,374 Actual generation as a percentage of average: 89%

Lake/Reservoir Levels Lake Powell’s elevation was 3,614 feet at the end of June, about 86 feet from maximum reservoir level and about 124 feet from the minimum generation level. Based on the current forecast, Lake Powell’s elevation will end water year (WY) 2015 near 3,604 feet with approximately 12.15 million acre-feet (MAF) in storage or 50 percent of capacity.

Weather and Other Conditions A dry winter in the Colorado River Basin reduced inflow estimates for Lake Powell, but wet conditions in May and June increased runoff projections to about 92 percent of the April through July average.

Desert Southwest Region

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 0.20 0.30 58.00 68.00 20.53 12.27 294,250 294,250 380,500 272,691 $0 $109,870 $106,819 Nov 14 1.80 3.90 54.00 44.00 20.57 12.41 325,000 372,000 363,500 357,310 $10,239 $22,472 $23,998 Dec 14 5.10 7.80 75.00 56.00 20.69 12.77 286,750 290,400 373,900 251,260 $294,966 $120 $534,300 Jan 15 8.70 9.40 93.00 72.00 20.84 13.01 411,100 411,100 398,400 428,462 $0 $0 $39,296 Feb 15 12.20 11.70 110.00 89.00 20.86 12.99 352,400 319,250 391,500 335,602 $0 $0 $8,661 Mar 15 15.80 12.60 105.00 57.00 20.66 12.69 543,600 526,100 531,400 560,224 $57,626 $94,756 $166,762 Apr 15 19.60 10.50 85.00 26.00 20.49 12.20 601,550 601,750 571,800 583,186 $0 $0 $7,714 May 15 19.90 8.30 60.00 26.00 20.61 12.03 555,600 530,800 573,200 466,936 $0 $0 $212,462 Jun 15 9.00 0.30 26.87 15.00 20.83 11.93 479,650 471,300 538,800 458,404 $163,991 $300,890 $467,114 Jul 15 Aug 15 Sep 15 Total 3,849,900 3,816,950 4,123,000 3,714,075 $526,822 $528,108 $1,567,126 Actual generation as a percentage of average: 90%

Lake/Reservoir Levels Lake Mead’s elevation was 1,075 feet at the end of June, about 145 feet below full storage level and about 25 feet from the minimum generation level.

Weather and Other Conditions The Desert Southwest Region’s hydrology is mostly dependent on the Colorado River Basin snowpack and precipitation above Lake Powell. Due to significantly above-average precipitation experienced during May, the probability that Lake Mead will be operating under the Shortage Criteria for WY 2016 is now negligible.

Rocky Mountain Region

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 139.20 200.80 3.84 4.47 99,021 102,458 83,694 91,560 $2,257,085 Nov 14 121.40 129.20 3.87 4.47 60,006 60,146 82,089 55,233 $3,178,702 Dec 14 97.90 139.40 3.83 4.47 89,969 90,045 103,710 88,510 $2,294,873 Jan 15 407.20 427.80 96.20 129.40 3.80 4.47 106,726 106,906 113,597 102,961 $2,614,295 $2,606,695 $2,203,620 Feb 15 808.10 739.20 95.00 128.60 3.80 4.51 85,735 86,024 102,200 79,516 $2,054,163 $2,042,763 $1,780,322 Mar 15 1,065.10 994.40 158.40 199.30 3.83 4.56 96,042 108,706 120,988 103,860 $2,128,149 $1,645,549 $1,726,554 Apr 15 1,341.70 1,016.80 253.10 257.80 3.85 4.60 125,443 138,545 140,995 128,526 $1,707,570 $1,278,170 $1,464,159 May 15 301.50 355.20 694.10 758.20 4.18 5.21 190,340 198,107 198,626 166,491 $180,000 $180,000 $1,022,010 Jun 15 1,109.20 1,462.30 4.76 5.69 263,985 259,220 243,234 223,790 $180,000 $180,000 $630,617 Jul 15 Aug 15 Sep 15 Total 1,117,266 1,150,155 1,189,133 1,040,447 $8,864,178 $7,933,178 $16,557,942 Actual generation as a percentage of average: 87%

Lake/Reservoir Content The overall reservoir content at the end of June was 120 percent of average.

Weather and Other Conditions The latest National Weather Service forecast calls for temperatures in the August through October period to be just as likely above as below normal in the Loveland Area Projects area, while precipitation is more likely to be above normal. The Bureau of Reclamation is now forecasting total spring reservoir inflows will be below average in the North Platte Basin, above average for the Colorado-Big Thompson Project, and well above average in the Bighorn Basin.

Note: Rocky Mountain Region (RMR)-related snowpack either is not measured or is relatively insignificant during the months of June through December. In addition, RMR does not project purchase power expenses for the months of October through December.

Sierra Nevada Region

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 329.00 263.00 5.61 2.49 161,181 106,181 163,000 115,957 $1,419,398 $1,419,398 $2,380,441 Nov 14 5.26 1.00 404.00 281.00 5.56 2.40 99,417 69,417 104,000 75,640 $1,314,004 $1,314,004 $2,396,084 Dec 14 4.94 5.00 1,014.00 1,450.00 6.06 3.66 69,042 0 143,000 13,282 $1,252,191 $1,252,191 $2,458,218 Jan 15 5.80 4.00 954.00 508.00 6.39 3.89 0 0 163,000 23,872 $1,508,460 $1,508,460 $2,077,046 Feb 15 9.00 5.00 997.00 1,232.00 6.92 4.93 0 14,968 195,000 29,080 $1,363,440 $1,363,440 $1,800,319 Mar 15 15.00 2.00 1,330.00 412.00 7.56 5.01 115,340 100,340 207,000 40,197 $1,506,498 $1,506,498 $1,974,521 Apr 15 10.00 1.00 1,245.00 341.00 7.95 4.91 171,316 231,316 288,000 126,768 $567,840 $567,840 $1,283,377 May 15 1,203.00 301.00 7.91 4.42 246,135 336,135 442,000 230,955 $576,240 $576,240 $1,270,668 Jun 15 739.00 251.00 7.44 3.97 337,065 457,065 440,000 295,101 $567,840 $567,840 $1,271,064 Jul 15 Aug 15 Sep 15 Total 1,199,496 1,315,422 2,145,000 950,852 $10,075,912 $10,075,912 $16,911,739 Actual generation as a percentage of average: 44%

Lake/Reservoir Content Accumulated inflow for the water year to date is 76 percent of average for Trinity, 72 percent for Shasta, 38 percent for Folsom, and 35 percent for New Melones. The overall reservoir content at the end of June was 53 percent of average.

Weather and Other Conditions As of May 8, the State of California water year type declaration was "critical" based upon the May 1 conditions 50 percent exceedence forecast. As of July 23, the cumulative precipitation was 36.73 inches or 73 percent of average for the Northern Sierra Eight Station Index.

Note: Sierra Nevada Region (SNR)-related snowpack is either is not measured or is relatively insignificant during the months of May through October. SNR’s average projection of generation is taken from the latest modeling using the update to its customers’ “Green Book,” and SNR does not project purchase power expenses for dry conditions.

Upper Great Plains Region

Snowpack Lake/Reservoir (Inches in Snow Lake/Reservoir Inflow Content Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (Megawatt-Hours) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Dry Probable Actual Oct 14 0.09 0.00 8,092.00 10,685.90 55.94 59.74 1,024,068 1,136,432 876,737 1,121,829 $0 $0 $0 Nov 14 1.20 0.30 7,411.00 8,616.60 54.83 58.09 963,501 1,068,021 793,241 953,548 $0 $0 $387,831 Dec 14 3.80 3.90 6,468.00 6,229.90 54.23 57.97 684,781 677,324 683,190 668,651 $16,358,337 $16,693,924 $7,638,795 Jan 15 7.10 7.30 6,658.00 6,786.10 53.94 58.03 709,312 761,724 726,502 742,726 $13,443,547 $11,084,984 $9,858,892 Feb 15 10.30 9.70 6,291.00 6,679.80 54.25 58.60 690,792 692,614 629,110 688,365 $11,147,066 $11,065,054 $5,910,668 Mar 15 12.90 11.50 8,226.00 7,837.90 56.02 59.12 836,705 780,645 656,996 805,343 $2,354,524 $4,877,224 $283,782 Apr 15 15.80 10.70 8,061.00 9,554.70 56.91 55.89 961,825 925,659 744,680 854,325 $0 $0 $0 May 15 15.10 9.10 9,699.00 9,287.30 58.18 60.04 924,575 904,285 901,082 860,028 $0 $0 $0 Jun 15 6.60 2.30 11,819.00 11,339.70 60.38 61.93 844,485 806,191 892,270 838,454 $0 $1,312,834 $0 Jul 15 Aug 15 Sep 15 Total 7,640,042 7,752,893 6,903,808 7,533,269 $43,303,473 $45,034,020 $24,079,968 Actual generation as a percentage of average: 109%

Lake/Reservoir Content As of July 8, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 96.4 percent and 100 percent full, respectively.

Weather and Other Conditions June was another wet month with runoff of 6.82 MAF or 125 percent of normal. The July forecast runoff above Sioux City for 2015 is 26.6 MAF or 105 percent of normal, which is a large increase from last month's forecast of 22.5 MAF. The increased runoff will provide additional energy for the fall and winter months and allow the Missouri River system to start 2016 with full reservoirs.

Note: The Upper Great Plains Region reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation.

Western Area Power Administration Hydro Conditions and Purchase Power Report August 2015

Western-Wide

Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 14 1,826,532 1,977,668 1,886,361 1,959,502 217,758 $8,123,479 $4,518,858 $8,459,359 Nov 14 1,678,876 1,878,130 1,730,985 1,779,466 500,496 $8,874,069 $5,574,443 $20,099,121 Dec 14 1,400,852 1,466,433 1,741,762 1,495,299 512,670 $25,598,065 $19,898,668 $22,600,706 Jan 15 1,582,275 1,685,555 1,858,893 1,772,024 494,032 $21,978,980 $17,467,062 $18,490,242 Feb 15 1,394,573 1,413,966 1,708,390 1,455,474 421,653 $19,588,891 $18,262,214 $15,884,393 Mar 15 1,864,152 1,820,595 1,906,554 1,862,739 441,594 $11,564,400 $12,466,384 $12,141,557 Apr 15 2,110,829 2,225,796 2,143,336 2,025,729 346,309 $5,743,735 $3,508,301 $7,880,103 May 15 2,236,720 2,352,849 2,616,795 2,175,381 211,432 $2,800,825 $1,217,038 $4,448,474 Jun 15 2,262,474 2,393,989 2,699,771 2,359,536 184,539 $3,213,271 $2,965,229 $5,358,853 Jul 15 2,361,247 2,456,073 2,963,554 2,252,737 134,715 $6,466,623 $6,989,211 $4,917,733 Aug 15 Sep 15 Total 18,718,530 19,671,054 21,256,400 19,137,887 3,465,198 $113,952,338 $92,867,408 $120,280,541 Actual generation as a percentage of average: 90% Cost per MWh: $34.71

Western Area Power Administration (Western) generated a total of 19,138 gigawatt-hours (GWh) during October through July of fiscal year 2015, or 90 percent of the average. For the same period, total purchase power was 3,465 GWh and total purchase power expenses were $120,280,541, which equates to $34.71 per MWh.

Colorado River Storage Project

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 14 0.20 0.30 408.80 636.00 15.01 12.29 248,012 338,348 382,430 357,465 87,211 $6,704,081 $2,989,589 $3,353,763 Nov 14 1.80 3.90 510.71 420.00 14.91 11.93 230,952 308,547 388,155 337,735 139,836 $7,549,826 $4,237,967 $5,504,854 Dec 14 5.10 7.80 474.22 465.00 14.86 11.54 270,310 408,665 437,962 473,595 36,641 $7,692,571 $1,952,432 $1,405,094 Jan 15 8.70 9.40 363.30 449.00 14.98 11.15 355,138 405,825 457,394 474,003 40,968 $4,412,679 $2,266,923 $1,523,337 Feb 15 12.20 11.70 362.24 464.00 15.99 11.02 265,647 301,110 390,580 322,910 116,656 $5,024,221 $3,790,958 $3,744,097 Mar 15 15.80 12.60 391.67 543.00 16.77 10.91 272,465 304,805 390,170 353,115 122,197 $5,517,603 $4,342,357 $3,876,509 Apr 15 19.60 10.50 665.00 539.00 16.74 10.84 250,695 328,527 397,861 332,925 75,298 $3,468,325 $1,662,291 $1,968,191 May 15 19.90 8.30 1,059.34 1,431.00 16.30 11.49 320,070 383,522 501,886 450,972 6,927 $2,044,585 $460,798 $172,668 Jun 15 9.00 0.30 2,339.33 2,570.00 16.00 13.09 337,289 400,213 585,467 543,787 4,310 $2,301,440 $603,666 $95,862 Jul 15 0.60 0.30 2,665.79 1,002.00 15.88 13.00 436,357 499,635 612,093 436,357 0 $708,807 $0 $0 Aug 15 Sep 15 Total 2,986,936 3,679,196 4,543,998 4,082,865 630,044 $45,424,137 $22,306,980 $21,644,374 Actual generation as a percentage of average: 90% Cost per MWh: $34.35

Lake/Reservoir Levels Lake Powell’s elevation was 3,613 feet at the end of July, about 87 feet from maximum reservoir level and about 123 feet from the minimum generation level. Based on the current forecast, Lake Powell’s elevation will end water year (WY) 2015 near 3,608 feet with approximately 12.51 million acre-feet (MAF) in storage or 51 percent of capacity.

Weather and Other Conditions No unusual conditions reported.

Desert Southwest Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 14 0.20 0.30 58.00 68.00 20.53 12.27 294,250 294,250 380,500 272,691 2,420 $0 $109,870 $106,819 Nov 14 1.80 3.90 54.00 44.00 20.57 12.41 325,000 372,000 363,500 357,310 530 $10,239 $22,472 $23,998 Dec 14 5.10 7.80 75.00 56.00 20.69 12.77 286,750 290,400 373,900 251,260 8,905 $294,966 $120 $534,300 Jan 15 8.70 9.40 93.00 72.00 20.84 13.01 411,100 411,100 398,400 428,462 1,179 $0 $0 $39,296 Feb 15 12.20 11.70 110.00 89.00 20.86 12.99 352,400 319,250 391,500 335,602 274 $0 $0 $8,661 Mar 15 15.80 12.60 105.00 57.00 20.66 12.69 543,600 526,100 531,400 560,224 5,187 $57,626 $94,756 $166,762 Apr 15 19.60 10.50 85.00 26.00 20.49 12.20 601,550 601,750 571,800 583,186 187 $0 $0 $7,714 May 15 19.90 8.30 60.00 26.00 20.61 12.03 555,600 530,800 573,200 466,936 5,005 $0 $0 $212,462 Jun 15 9.00 0.30 26.87 15.00 20.83 11.93 479,650 471,300 538,800 458,404 10,978 $163,991 $300,890 $467,114 Jul 15 0.60 0.30 65.95 81.00 20.73 12.13 467,200 463,150 551,200 411,961 26,265 $342,373 $536,409 $1,325,069 Aug 15 Sep 15 Total 4,317,100 4,280,100 4,674,200 4,126,036 60,930 $869,195 $1,064,517 $2,892,195 Actual generation as a percentage of average: 88% Cost per MWh: $47.47

Lake/Reservoir Levels Lake Mead’s elevation was 1,078 feet at the end of July, about 142 feet below full storage level and about 28 feet from the minimum generation level.

Weather and Other Conditions The Desert Southwest Region’s hydrology is mostly dependent on the Colorado River Basin snowpack and precipitation above Lake Powell. The WY 2015 precipitation is currently 94 percent of average.

Rocky Mountain Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 14 139.20 200.80 3.84 4.47 99,021 102,458 83,694 91,560 53,455 $2,257,085 Nov 14 121.40 129.20 3.87 4.47 60,006 60,146 82,089 55,233 91,858 $3,178,702 Dec 14 97.90 139.40 3.83 4.47 89,969 90,045 103,710 88,510 61,151 $2,294,873 Jan 15 407.20 427.80 96.20 129.40 3.80 4.47 106,726 106,906 113,597 102,961 43,082 $2,614,295 $2,606,695 $1,248,645 Feb 15 808.10 739.20 95.00 128.60 3.80 4.51 85,735 86,024 102,200 79,516 37,133 $2,054,163 $2,042,763 $1,136,969 Mar 15 1,065.10 994.40 158.40 199.30 3.83 4.56 96,042 108,706 120,988 103,860 38,228 $2,128,149 $1,645,549 $1,066,792 Apr 15 1,341.70 1,016.80 253.10 257.80 3.85 4.60 125,443 138,545 140,995 128,526 46,418 $1,707,570 $1,278,170 $945,079 May 15 301.50 355.20 694.10 758.20 4.18 5.21 190,340 198,107 198,626 166,491 40,171 $180,000 $180,000 $1,022,010 Jun 15 1,105.70 1,462.30 4.74 5.69 263,985 259,220 243,234 223,790 15,197 $180,000 $180,000 $585,003 Jul 15 521.10 382.40 4.45 5.36 219,918 225,508 257,413 213,347 55,749 $249,600 $287,258 $1,859,733 Aug 15 Sep 15 Total 1,337,184 1,375,663 1,446,546 1,253,794 482,442 $9,113,778 $8,220,436 $15,594,891 Actual generation as a percentage of average: 87% Cost per MWh: $32.32

Lake/Reservoir Content The overall reservoir content at the end of July was 120 percent of average.

Weather and Other Conditions None of the Loveland Area Projects (LAP) area is considered to be in any level of drought status. The latest National Weather Service forecast indicates September through November temperatures are just as likely to be above as below normal for the Colorado-Big Thompson Project and North Platte Basin and more likely to be above normal in the Bighorn Basin, and the precipitation is more likely to be above average throughout the LAP area.

Sierra Nevada Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 14 329.00 263.00 5.61 2.49 161,181 106,181 163,000 115,957 56,702 $1,419,398 $1,419,398 $2,380,441 Nov 14 5.26 1.00 404.00 281.00 5.56 2.40 99,417 69,417 104,000 75,640 53,074 $1,314,004 $1,314,004 $2,396,084 Dec 14 4.94 5.00 1,014.00 1,450.00 6.06 3.66 69,042 0 143,000 13,282 60,541 $1,252,191 $1,252,191 $2,458,218 Jan 15 5.80 4.00 954.00 508.00 6.39 3.89 0 0 163,000 23,872 62,660 $1,508,460 $1,508,460 $2,077,046 Feb 15 9.00 5.00 997.00 1,232.00 6.92 4.93 0 14,968 195,000 29,080 55,937 $1,363,440 $1,363,440 $1,800,319 Mar 15 15.00 2.00 1,330.00 412.00 7.56 5.01 115,340 100,340 207,000 40,197 61,698 $1,506,498 $1,506,498 $1,974,521 Apr 15 10.00 1.00 1,245.00 341.00 7.95 4.91 171,316 231,316 288,000 126,768 53,919 $567,840 $567,840 $1,283,377 May 15 1,203.00 301.00 7.91 4.42 246,135 336,135 442,000 230,955 48,416 $576,240 $576,240 $1,270,668 Jun 15 739.00 251.00 7.44 3.97 337,065 457,065 440,000 295,101 50,921 $567,840 $567,840 $1,271,064 Jul 15 434.00 225.00 6.70 3.50 349,780 404,780 524,000 316,029 52,701 $1,444,840 $1,444,840 $1,732,931 Aug 15 Sep 15 Total 1,549,276 1,720,202 2,669,000 1,266,881 556,569 $11,520,752 $11,520,752 $18,644,669 Actual generation as a percentage of average: 47% Cost per MWh: $33.50

Lake/Reservoir Content Accumulated inflow for the water year to date is 75 percent of average for Trinity, 72 percent for Shasta, 39 percent for Folsom, and 35 percent for New Melones. The overall reservoir content at the end of July was 52 percent of average.

Weather and Other Conditions As of May 8, the State of California water year type declaration was "critical" based upon the May 1 conditions 50 percent exceedence forecast. As of August 25, the cumulative precipitation was 36.75 inches or 73 percent of average for the Northern Sierra Eight Station Index.

Upper Great Plains Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 14 0.09 0.00 8,092.00 10,685.90 55.94 59.74 1,024,068 1,136,432 876,737 1,121,829 17,970 $0 $0 $361,250 Nov 14 1.20 0.30 7,411.00 8,616.60 54.83 58.09 963,501 1,068,021 793,241 953,548 215,198 $0 $0 $8,995,483 Dec 14 3.80 3.90 6,468.00 6,229.90 54.23 57.97 684,781 677,324 683,190 668,651 345,432 $16,358,337 $16,693,924 $15,908,221 Jan 15 7.10 7.30 6,658.00 6,786.10 53.94 58.03 709,312 761,724 726,502 742,726 346,143 $13,443,547 $11,084,984 $13,601,918 Feb 15 10.30 9.70 6,291.00 6,679.80 54.25 58.60 690,792 692,614 629,110 688,365 211,653 $11,147,066 $11,065,054 $9,194,348 Mar 15 12.90 11.50 8,226.00 7,837.90 56.02 59.12 836,705 780,645 656,996 805,343 214,284 $2,354,524 $4,877,224 $5,056,973 Apr 15 15.80 10.70 8,061.00 9,554.70 56.91 55.89 961,825 925,659 744,680 854,325 170,487 $0 $0 $3,675,743 May 15 15.10 9.10 9,699.00 9,287.30 58.18 60.04 924,575 904,285 901,082 860,028 110,913 $0 $0 $1,770,665 Jun 15 6.60 2.30 11,819.00 11,339.70 60.38 61.93 844,485 806,191 892,270 838,454 103,133 $0 $1,312,834 $2,939,810 Jul 15 0.60 0.00 10,827.00 9,376.20 60.36 62.45 887,993 863,000 1,018,848 875,042 0 $3,721,004 $4,720,704 $0 Aug 15 Sep 15 Total 8,528,035 8,615,893 7,922,656 8,408,311 1,735,213 $47,024,477 $49,754,723 $61,504,411 Actual generation as a percentage of average: 106% Cost per MWh: $35.44

Lake/Reservoir Content As of August 16, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 87.3 percent and 98.4 percent full, respectively.

Weather and Other Conditions Dry conditions are moving into northern and western Montana, and warm summer temperatures have decreased stream flows particularly in western Montana. For July, runoff above Sioux City was only 2.7 MAF or 81 percent of normal. The August forecast runoff above Sioux City is 25 MAF or 99 percent of normal, which is a significant decrease from last month's forecast of 26.6 MAF. The decreased runoff will reduce energy for the fall and winter months, but system storage is still in good shape.

Note: The Upper Great Plains Region reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation.

Western Area Power Administration Hydro Conditions and Purchase Power Report September 2015

Western-Wide

Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 14 1,826,532 1,977,668 1,886,361 1,959,502 217,758 $8,123,479 $4,518,858 $8,459,359 Nov 14 1,678,876 1,878,130 1,730,985 1,779,466 500,496 $8,874,069 $5,574,443 $20,099,121 Dec 14 1,400,852 1,466,433 1,741,762 1,495,299 512,670 $25,598,065 $19,898,668 $22,600,706 Jan 15 1,582,275 1,685,555 1,858,893 1,772,024 494,032 $21,978,980 $17,467,062 $18,490,242 Feb 15 1,394,573 1,413,966 1,708,390 1,455,474 421,653 $19,588,891 $18,262,214 $15,884,393 Mar 15 1,864,152 1,820,595 1,906,554 1,862,739 441,594 $11,564,400 $12,466,384 $12,141,557 Apr 15 2,110,829 2,225,796 2,143,336 2,025,729 346,309 $5,743,735 $3,508,301 $7,880,103 May 15 2,236,720 2,352,849 2,616,795 2,175,381 211,432 $2,800,825 $1,217,038 $4,448,474 Jun 15 2,262,474 2,393,989 2,699,771 2,359,536 184,539 $3,213,271 $2,965,229 $5,358,853 Jul 15 2,361,247 2,456,073 2,963,554 2,471,035 237,963 $6,466,623 $6,989,211 $8,240,596 Aug 15 2,196,185 2,298,318 2,764,387 2,258,993 132,608 $5,393,773 $4,964,505 $4,512,294 Sep 15 Total 20,914,715 21,969,371 24,020,787 21,615,178 3,701,054 $119,346,111 $97,831,913 $128,115,698 Actual generation as a percentage of average: 90% Cost per MWh: $34.62

Western Area Power Administration (Western) generated a total of 21,615 gigawatt-hours (GWh) during October through August of fiscal year 2015, or 90 percent of the average. For the same period, total purchase power was 3,701 GWh and total purchase power expenses were $128,115,698, which equates to $34.62 per MWh.

Colorado River Storage Project

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 14 0.20 0.30 408.80 636.00 15.01 12.29 248,012 338,348 382,430 357,465 87,211 $6,704,081 $2,989,589 $3,353,763 Nov 14 1.80 3.90 510.71 420.00 14.91 11.93 230,952 308,547 388,155 337,735 139,836 $7,549,826 $4,237,967 $5,504,854 Dec 14 5.10 7.80 474.22 465.00 14.86 11.54 270,310 408,665 437,962 473,595 36,641 $7,692,571 $1,952,432 $1,405,094 Jan 15 8.70 9.40 363.30 449.00 14.98 11.15 355,138 405,825 457,394 474,003 40,968 $4,412,679 $2,266,923 $1,523,337 Feb 15 12.20 11.70 362.24 464.00 15.99 11.02 265,647 301,110 390,580 322,910 116,656 $5,024,221 $3,790,958 $3,744,097 Mar 15 15.80 12.60 391.67 543.00 16.77 10.91 272,465 304,805 390,170 353,115 122,197 $5,517,603 $4,342,357 $3,876,509 Apr 15 19.60 10.50 665.00 539.00 16.74 10.84 250,695 328,527 397,861 332,925 75,298 $3,468,325 $1,662,291 $1,968,191 May 15 19.90 8.30 1,059.34 1,431.00 16.30 11.49 320,070 383,522 501,886 450,972 6,927 $2,044,585 $460,798 $172,668 Jun 15 9.00 0.30 2,339.33 2,570.00 16.00 13.09 337,289 400,213 585,467 543,787 4,310 $2,301,440 $603,666 $95,862 Jul 15 0.60 0.30 2,665.79 1,002.00 15.88 13.00 436,357 499,635 612,093 654,656 0 $708,807 $0 $0 Aug 15 0.00 0.00 1,088.30 466.00 15.68 12.37 429,891 511,788 574,470 511,788 12,123 $1,004,331 $0 $313,612 Sep 15 Total 3,416,827 4,190,984 5,118,468 4,812,952 642,167 $46,428,468 $22,306,980 $21,957,986 Actual generation as a percentage of average: 94% Cost per MWh: $34.19

Lake/Reservoir Levels Lake Powell’s elevation was 3,609 feet at the end of August, about 91 feet from maximum reservoir level and about 119 feet from the minimum generation level. Based on the current forecast, Lake Powell’s elevation will end water year (WY) 2015 near 3,607 feet with approximately 12.38 million acre-feet (MAF) in storage or 51 percent of capacity.

Weather and Other Conditions No unusual conditions reported.

Desert Southwest Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 14 0.20 0.30 58.00 68.00 20.53 12.27 294,250 294,250 380,500 272,691 2,420 $0 $109,870 $106,819 Nov 14 1.80 3.90 54.00 44.00 20.57 12.41 325,000 372,000 363,500 357,310 530 $10,239 $22,472 $23,998 Dec 14 5.10 7.80 75.00 56.00 20.69 12.77 286,750 290,400 373,900 251,260 8,905 $294,966 $120 $534,300 Jan 15 8.70 9.40 93.00 72.00 20.84 13.01 411,100 411,100 398,400 428,462 1,179 $0 $0 $39,296 Feb 15 12.20 11.70 110.00 89.00 20.86 12.99 352,400 319,250 391,500 335,602 274 $0 $0 $8,661 Mar 15 15.80 12.60 105.00 57.00 20.66 12.69 543,600 526,100 531,400 560,224 5,187 $57,626 $94,756 $166,762 Apr 15 19.60 10.50 85.00 26.00 20.49 12.20 601,550 601,750 571,800 583,186 187 $0 $0 $7,714 May 15 19.90 8.30 60.00 26.00 20.61 12.03 555,600 530,800 573,200 466,936 5,005 $0 $0 $212,462 Jun 15 9.00 0.30 26.87 15.00 20.83 11.93 479,650 471,300 538,800 458,404 10,978 $163,991 $300,890 $467,114 Jul 15 0.60 0.30 65.95 81.00 20.73 12.13 467,200 463,150 551,200 411,961 26,265 $342,373 $536,409 $1,325,069 Aug 15 0.00 0.00 99.66 115.00 20.60 12.13 406,900 406,900 515,700 427,419 23,805 $979,257 $974,741 $1,197,370 Sep 15 Total 4,724,000 4,687,000 5,189,900 4,553,455 84,735 $1,848,452 $2,039,258 $4,089,565 Actual generation as a percentage of average: 88% Cost per MWh: $48.26

Lake/Reservoir Levels Lake Mead’s elevation was 1,078 feet at the end of August, about 141 feet below full storage level and about 28 feet from the minimum generation level.

Rocky Mountain Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 14 139.20 200.80 3.84 4.47 99,021 102,458 83,694 91,560 53,455 $2,257,085 Nov 14 121.40 129.20 3.87 4.47 60,006 60,146 82,089 55,233 91,858 $3,178,702 Dec 14 97.90 139.40 3.83 4.47 89,969 90,045 103,710 88,510 61,151 $2,294,873 Jan 15 407.20 427.80 96.20 129.40 3.80 4.47 106,726 106,906 113,597 102,961 43,082 $2,614,295 $2,606,695 $1,248,645 Feb 15 808.10 739.20 95.00 128.60 3.80 4.51 85,735 86,024 102,200 79,516 37,133 $2,054,163 $2,042,763 $1,136,969 Mar 15 1,065.10 994.40 158.40 199.30 3.83 4.56 96,042 108,706 120,988 103,860 38,228 $2,128,149 $1,645,549 $1,066,792 Apr 15 1,341.70 1,016.80 253.10 257.80 3.85 4.60 125,443 138,545 140,995 128,526 46,418 $1,707,570 $1,278,170 $945,079 May 15 301.50 355.20 694.10 758.20 4.18 5.21 190,340 198,107 198,626 166,491 40,171 $180,000 $180,000 $1,022,010 Jun 15 1,105.70 1,462.30 4.74 5.69 263,985 259,220 243,234 223,790 15,197 $180,000 $180,000 $585,003 Jul 15 521.10 382.40 4.45 5.36 219,918 225,508 257,413 213,347 44,520 $249,600 $287,258 $1,696,970 Aug 15 188.60 124.00 4.00 4.83 200,091 206,451 205,091 168,316 42,744 $296,240 $230,880 $1,251,840 Sep 15 Total 1,537,275 1,582,114 1,651,637 1,422,110 513,957 $9,410,018 $8,451,316 $16,683,968 Actual generation as a percentage of average: 86% Cost per MWh: $32.46

Lake/Reservoir Content The overall reservoir content at the end of August was 121 percent of average.

Weather and Other Conditions None of the Loveland Area Projects (LAP) area is considered to be in any level of drought status. The latest National Weather Service forecast indicates October through December temperatures are just as likely to be above as below normal in the LAP area, and the precipitation is more likely to be above normal in Colorado while just as likely to be above as below normal in Wyoming.

Sierra Nevada Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 14 329.00 263.00 5.61 2.49 161,181 106,181 163,000 115,957 56,702 $1,419,398 $1,419,398 $2,380,441 Nov 14 5.26 1.00 404.00 281.00 5.56 2.40 99,417 69,417 104,000 75,640 53,074 $1,314,004 $1,314,004 $2,396,084 Dec 14 4.94 5.00 1,014.00 1,450.00 6.06 3.66 69,042 0 143,000 13,282 60,541 $1,252,191 $1,252,191 $2,458,218 Jan 15 5.80 4.00 954.00 508.00 6.39 3.89 0 0 163,000 23,872 62,660 $1,508,460 $1,508,460 $2,077,046 Feb 15 9.00 5.00 997.00 1,232.00 6.92 4.93 0 14,968 195,000 29,080 55,937 $1,363,440 $1,363,440 $1,800,319 Mar 15 15.00 2.00 1,330.00 412.00 7.56 5.01 115,340 100,340 207,000 40,197 61,698 $1,506,498 $1,506,498 $1,974,521 Apr 15 10.00 1.00 1,245.00 341.00 7.95 4.91 171,316 231,316 288,000 126,768 53,919 $567,840 $567,840 $1,283,377 May 15 1,203.00 301.00 7.91 4.42 246,135 336,135 442,000 230,955 48,416 $576,240 $576,240 $1,270,668 Jun 15 739.00 251.00 7.44 3.97 337,065 457,065 440,000 295,101 50,921 $567,840 $567,840 $1,271,064 Jul 15 434.00 225.00 6.70 3.50 349,780 404,780 524,000 316,029 52,701 $1,444,840 $1,444,840 $1,732,931 Aug 15 347.00 224.00 5.97 2.96 255,220 285,220 402,000 271,148 53,936 $1,444,840 $1,444,840 $1,749,472 Sep 15 Total 1,804,496 2,005,422 3,071,000 1,538,029 610,505 $12,965,592 $12,965,592 $20,394,141 Actual generation as a percentage of average: 50% Cost per MWh: $33.41

Lake/Reservoir Content Accumulated inflow for the water year to date is 75 percent of average for Trinity, 72 percent for Shasta, 40 percent for Folsom, and 37 percent for New Melones. The overall reservoir content at the end of August was 50 percent of average.

Weather and Other Conditions As of May 8, the State of California water year type declaration was "critical" based upon the May 1 conditions 50 percent exceedence forecast. As of September 22, the cumulative precipitation was 37.24 inches or 74 percent of average for the Northern Sierra Eight Station Index.

Upper Great Plains Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 14 0.09 0.00 8,092.00 10,685.90 55.94 59.74 1,024,068 1,136,432 876,737 1,121,829 17,970 $0 $0 $361,250 Nov 14 1.20 0.30 7,411.00 8,616.60 54.83 58.09 963,501 1,068,021 793,241 953,548 215,198 $0 $0 $8,995,483 Dec 14 3.80 3.90 6,468.00 6,229.90 54.23 57.97 684,781 677,324 683,190 668,651 345,432 $16,358,337 $16,693,924 $15,908,221 Jan 15 7.10 7.30 6,658.00 6,786.10 53.94 58.03 709,312 761,724 726,502 742,726 346,143 $13,443,547 $11,084,984 $13,601,918 Feb 15 10.30 9.70 6,291.00 6,679.80 54.25 58.60 690,792 692,614 629,110 688,365 211,653 $11,147,066 $11,065,054 $9,194,348 Mar 15 12.90 11.50 8,226.00 7,837.90 56.02 59.12 836,705 780,645 656,996 805,343 214,284 $2,354,524 $4,877,224 $5,056,973 Apr 15 15.80 10.70 8,061.00 9,554.70 56.91 55.89 961,825 925,659 744,680 854,325 170,487 $0 $0 $3,675,743 May 15 15.10 9.10 9,699.00 9,287.30 58.18 60.04 924,575 904,285 901,082 860,028 110,913 $0 $0 $1,770,665 Jun 15 6.60 2.30 11,819.00 11,339.70 60.38 61.93 844,485 806,191 892,270 838,454 103,133 $0 $1,312,834 $2,939,810 Jul 15 0.60 0.00 10,827.00 9,376.20 60.36 62.45 887,993 863,000 1,018,848 875,042 114,477 $3,721,004 $4,720,704 $3,485,626 Aug 15 0.00 0.00 9,829.00 10,099.50 58.77 62.90 904,083 887,960 1,067,126 880,322 0 $1,669,104 $2,314,044 $0 Sep 15 Total 9,432,118 9,503,852 8,989,782 9,288,633 1,849,690 $48,693,581 $52,068,767 $64,990,037 Actual generation as a percentage of average: 103% Cost per MWh: $35.14

Lake/Reservoir Content As of September 9, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 81.5 percent and 97.0 percent full, respectively.

Weather and Other Conditions For August, runoff above Sioux City was 1.5 MAF or 110 percent of normal.

Note: The Upper Great Plains Region reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation.

Western Area Power Administration Hydro Conditions and Purchase Power Report January 2016

Western-Wide

Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1,434,895 1,538,279 1,966,014 1,614,375 214,812 $14,857,785 $11,511,540 $6,389,635 Nov 15 1,378,403 1,448,916 1,852,469 1,393,430 260,407 $18,049,243 $16,350,999 $7,198,763 Dec 15 1,325,629 1,506,717 1,755,293 1,519,184 180,057 $24,259,449 $18,588,528 $5,314,823 Jan 16 Feb 16 Mar 16 Apr 16 May 16 Jun 16 Jul 16 Aug 16 Sep 16 Total 4,138,928 4,493,911 5,573,775 4,526,990 655,276 $57,166,478 $46,451,067 $18,903,221 Actual generation as a percentage of average: 81.2% Cost per MWh: $28.85

Western Area Power Administration (Western) generated a total of 4,527 gigawatt-hours (GWh) during October through December of fiscal year 2016, or 81.2 percent of the average. For the same period, estimated total purchase power was 655 GWh and estimated total purchase power expenses were $18,903,221, which equates to $28.85 per MWh.

Colorado River Storage Project

Lake/Reservoir Levels Lake Powell’s elevation was 3,601 feet at the end of December, about 99 feet below the maximum reservoir level and about 111 feet above the minimum generation level. Current storage volume for Lake Powell is 11,631,000 acre feet, which is about 49 percent of capacity.

Weather and Other Conditions No unusual conditions reported.

Desert Southwest Region

Lake/Reservoir Levels Lake Mead’s elevation was 1,081 feet at the end of December, about 139 feet below full storage level and about 31 feet above the minimum generation level.

Weather and Other Conditions The Desert Southwest Region’s hydrology is mostly dependent on the Colorado River Basin snowpack and precipitation above Lake Powell. The WY 2016 precipitation is currently 102 percent of average.

Rocky Mountain Region

Lake/Reservoir Content The overall reservoir content at the end of December was 116 percent of average.

Weather and Other Conditions The LAP area remains drought free but with dryer than normal conditions developing in some places. The very early snowpack is well above average for the Colorado-Big Thompson Project, below average in the Bighorn Basin, and well below average in the North Platte Basin. The latest National Weather Service forecast indicates December through February temperatures are more likely to be above normal in Wyoming and just as likely to be above as below normal in Colorado. The precipitation is more likely to be above normal in Colorado while more likely to be below normal in Wyoming.

Sierra Nevada Region

Lake/Reservoir Content As of January 26, accumulated inflow for the water year was 82 percent of the 15-year average for Trinity, 89 percent for Shasta, 73 percent for Folsom, and 91 percent for New Melones. The overall reservoir content at the end of December was 43 percent of average.

Weather and Other Conditions Cumulative precipitation of the Northern Sierra Eight Station Index is at 104 percent of average for this date, and 58 percent of the water year average. Forecasts began in December and are updated monthly based upon conditions as of the 1st of each month. The current January 1, 2016 forecast is "critical" for the dry (90 percent) and "dry" for the most probable (50 percent) exceedence cases.

Note: SNR’s average projection of generation is taken from the latest modeling using the update to its customers’ “Green Book.” SNR does not project purchase power expenses for dry conditions, and its most probable projected expenses are based upon term purchases of 70-75 percent of projected power needs with the difference being left to day-ahead markets after project pumping and generation are scheduled.

Upper Great Plains Region

Lake/Reservoir Content As of January 19, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 77.7 percent and 86.2 percent full, respectively.

Weather and Other Conditions A strong El Nino remains in place this winter but this has not stopped moisture from falling in the lower reaches of the Missouri River Basin. The December actual system runoff was 155 percent of average. Higher releases over the next few months will require fewer purchases to meet firm loads.

Note: The Upper Great Plains Region (UGPR) reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation. UGPR’s financial reports have not been completely updated for market charges, so UGPR is unable to report accurate purchase power data at this time.

Western Area Power Administration Hydro Conditions and Purchase Power Report February 2016

Western-Wide

Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1,434,895 1,538,279 1,966,014 1,614,375 225,012 $13,412,993 $10,002,458 $7,365,916 Nov 15 1,378,403 1,448,916 1,852,469 1,393,430 413,747 $16,197,285 $14,195,619 $10,070,025 Dec 15 1,325,629 1,506,717 1,755,293 1,519,184 506,729 $19,371,552 $13,648,145 $10,672,273 Jan 16 1,709,435 1,760,027 1,882,890 1,744,703 252,494 $9,493,892 $5,902,813 $7,017,678 Feb 16 Mar 16 Apr 16 May 16 Jun 16 Jul 16 Aug 16 Sep 16 Total 5,848,363 6,253,938 7,456,666 6,271,692 1,397,982 $58,475,723 $43,749,035 $35,125,891 Actual generation as a percentage of average: 84.1% Cost per MWh: $25.13

Western Area Power Administration (Western) generated a total of 6,272 gigawatt-hours (GWh) during October through January of fiscal year 2016, or 84.1 percent of the average. For the same period, total purchase power was 1,398 GWh and total purchase power expenses were $35,125,891, which equates to $25.13 per MWh.

Colorado River Storage Project

Lake/Reservoir Levels Lake Powell’s elevation was 3,597 feet at the end of January, about 103 feet below the maximum reservoir level and about 107 feet above the minimum generation level. Current storage volume for Lake Powell is 11,427,000 acre-feet, which is about 47 percent of capacity.

Weather and Other Conditions No unusual conditions reported.

Desert Southwest Region

Lake/Reservoir Levels Lake Mead’s elevation was 1,084 feet at the end of January, about 136 feet below full storage level and about 34 feet above the minimum generation level.

Rocky Mountain Region

Lake/Reservoir Content The overall reservoir content at the end of January was 116 percent of average.

Weather and Other Conditions While the Loveland Area Projects area is mostly drought free parts of the Bighorn Basin are now considered to be in a state of drought. The snowpack is above average for the Colorado-Big Thompson Project, below average in the North Platte Basin, and well below average in the Bighorn Basin. The latest National Weather Service forecast indicates March through May temperatures are more likely to be above normal in Wyoming and just as likely to be above as below normal in Colorado. The precipitation is more likely to be above normal in Colorado and southern Wyoming and just as likely to be above as below normal in northern Wyoming.

Sierra Nevada Region

Lake/Reservoir Content As of February 22, accumulated inflow for the water year was 106 percent of the 15-year average for Trinity, 97 percent for Shasta, 101 percent for Folsom, and 100 percent for New Melones. The overall reservoir content at the end of January was 64 percent of average.

Weather and Other Conditions As of February 22, cumulative precipitation of the Northern Sierra Eight Station Index is at 99 percent of average for the date, and 71 percent of the water year average. Forecasts began in December and are updated monthly based upon conditions as of the 1st of each month. The February 1, 2016 forecast is "critical" for the dry (90 percent) and "dry" for the most probable (50 percent) exceedence cases.

Note: The Sierra Nevada Region’s (SNR) average projection of generation is taken from the latest modeling using the update to its customers’ “Green Book.” SNR does not project purchase power expenses for dry conditions, and its most probable projected expenses are based upon term purchases of 70-75 percent of projected power needs with the difference being left to day-ahead markets after project pumping and generation are scheduled.

Upper Great Plains Region

Lake/Reservoir Content As of February 16, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 77.8 percent and 84.2 percent full, respectively.

Weather and Other Conditions A strong El Nino continues to be in place this winter, bringing milder than normal temperatures to the upper Great Plains. The January actual system runoff was 114 percent of average above Sioux City. As of February 1, snowpack was less than normal at 92 percent above Fort Peck and 72 percent between Fort Peck and Garrison.

Note: The Upper Great Plains Region (UGPR) reports its 50 percent share of generation from Yellowtail Dam, while the Rocky Mountain Region reports the snowpack, inflow, content, and remaining share of generation. UGPR’s financial reports are in the process of being finalized, so the data indicated above may change.

Western Area Power Administration Hydro Conditions and Purchase Power Report March 2016

Western-Wide

Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1,434,895 1,538,279 1,966,014 1,612,157 273,603 $13,412,993 $10,002,458 $7,576,439 Nov 15 1,378,403 1,448,916 1,852,469 1,385,316 433,893 $16,197,285 $14,195,619 $10,102,495 Dec 15 1,325,629 1,506,717 1,755,293 1,497,975 519,702 $19,371,552 $13,648,145 $11,006,080 Jan 16 1,709,435 1,760,027 1,882,890 1,735,645 297,093 $9,493,892 $5,902,813 $7,045,364 Feb 16 1,365,511 1,491,899 1,746,941 1,516,513 143,174 $12,320,267 $8,662,264 $3,873,728 Mar 16 Apr 16 May 16 Jun 16 Jul 16 Aug 16 Sep 16 Total 7,213,874 7,745,836 9,203,606 7,747,606 1,667,464 $70,795,990 $52,411,299 $39,604,106 Actual generation as a percentage of average: 84.2% Cost per MWh: $23.75

Western Area Power Administration (Western) generated a total of 7,748 gigawatt-hours (GWh) during October through February of fiscal year 2016, or 84.2 percent of the average. For the same period, total purchase power was 1,667 GWh and total purchase power expenses were $39,604,106, which equates to $23.75 per MWh.

Colorado River Storage Project

Lake/Reservoir Levels Lake Powell’s elevation was 3,594 feet at the end of February, about 106 feet below the maximum reservoir level and about 104 feet above the minimum generation level. Current storage volume for Lake Powell is 11,200,000 acre-feet, which is about 46 percent of capacity.

Weather and Other Conditions No unusual conditions reported.

Desert Southwest Region

Lake/Reservoir Levels Lake Mead’s elevation was 1,084 feet at the end of February, about 135 feet below full storage level and about 34 feet above the minimum generation level.

Rocky Mountain Region

Lake/Reservoir Content The overall reservoir content at the end of February was 117 percent of average.

Weather and Other Conditions While the Loveland Area Projects area is mostly drought free parts of the Bighorn Basin are now considered to be in a state of drought. The snowpack is average for the Colorado-Big Thompson Project, below average in the North Platte Basin, and well below average in the Bighorn Basin. The latest National Weather Service forecast indicates April through June temperatures are more likely to be above normal in Wyoming and western and north central Colorado, and just as likely to be above as below normal in eastern and south central Colorado. The precipitation is more likely to be above normal in both Colorado and Wyoming.

Note: The Rocky Mountain Region’s (RMR) more recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Lake/Reservoir Content As of March 15, accumulated inflow for the water year was 145 percent of the 15-year average for Trinity, 121 percent for Shasta, 127 percent for Folsom, and 114 percent for New Melones. The overall reservoir content at the end of February was 70 percent of average.

Weather and Other Conditions As of March 15, cumulative precipitation of the Northern Sierra Eight Station Index is at 115 percent of average for the date, and 98 percent of the water year average. Forecasts began in December and are updated monthly based upon conditions as of the 1st of each month. The March 1, 2016 forecast is "critical" for the dry (90 percent) and "dry" for the most probable (50 percent) exceedence cases.

Upper Great Plains Region

Lake/Reservoir Content As of March 21, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 78.0 percent and 81.3 percent full, respectively.

Weather and Other Conditions Warmer-than-normal temperatures in February resulted in early melting of the plains snowpack, and the February actual system runoff was 170 percent of average above Sioux City. As of March 1, snowpack was at 88 percent above Fort Peck and 75 percent between Fort Peck and Garrison.

Note: The Upper Great Plains Region (UGPR) reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation. UGPR’s financial reports are in the process of being finalized, so its reported purchase power data may change.

Western Area Power Administration Hydro Conditions and Purchase Power Report April 2016

Western-Wide

Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1,434,895 1,538,279 1,966,014 1,612,157 265,079 $13,412,993 $10,002,458 $7,273,130 Nov 15 1,378,403 1,448,916 1,852,469 1,385,316 416,430 $16,197,285 $14,195,619 $9,530,629 Dec 15 1,325,629 1,506,717 1,755,293 1,497,975 493,359 $19,371,552 $13,648,145 $10,163,658 Jan 16 1,709,435 1,760,027 1,882,890 1,735,645 281,726 $9,493,892 $5,902,813 $6,768,708 Feb 16 1,365,511 1,491,899 1,746,941 1,516,513 379,479 $12,320,267 $8,662,264 $7,673,322 Mar 16 1,696,021 1,715,754 1,987,844 1,769,248 Apr 16 May 16 Jun 16 Jul 16 Aug 16 Sep 16 Total 8,909,895 9,461,590 11,191,451 9,516,853 1,836,072 $70,795,990 $52,411,299 $41,409,447 Actual generation as a percentage of average: 85.0% Cost per MWh: $22.55

Western Area Power Administration (Western) generated a total of 9,517 gigawatt-hours (GWh) during October through March of fiscal year 2016, or 85.0 percent of the average. Actual purchase power data is currently available from October through February for all of Western’s Regions, and during this period total purchase power was 1,836 GWh and total purchase power expenses were $41,409,447, which equates to $22.55 per MWh.

Colorado River Storage Project

Lake/Reservoir Levels Lake Powell’s elevation was 3,592 feet at the end of March, about 108 feet below the maximum reservoir level and about 102 feet above the minimum generation level. Current storage volume for Lake Powell is 11,019,000 acre-feet, which is about 45 percent of capacity.

Weather and Other Conditions No unusual conditions reported.

Desert Southwest Region

Lake/Reservoir Levels Lake Mead’s elevation was 1,080 feet at the end of March, about 139 feet below full storage level and about 30 feet above the minimum generation level.

Rocky Mountain Region

Lake/Reservoir Content The overall reservoir content at the end of March was 117 percent of average.

Weather and Other Conditions While the Loveland Area Projects area is mostly drought free, parts of the Bighorn Basin are now considered to be in a state of drought. The snowpack is above average for the Colorado-Big Thompson Project and near average in the North Platte and Bighorn Basins. The latest National Weather Service forecast indicates May through July temperatures are more likely to be above normal in Wyoming and just as likely to be above as below normal in Colorado. The precipitation is more likely to be above normal in both Colorado and Wyoming.

Note: The Rocky Mountain Region’s (RMR) most recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Lake/Reservoir Content As of March 31, accumulated inflow for the water year was 147 percent of the 15-year average for Trinity, 124 percent for Shasta, 131 percent for Folsom, and 117 percent for New Melones. Reservoir storage as of the same date was 73 percent of the 15-year average for Trinity, 112 percent for Shasta, 109 percent for Folsom, and 42 percent for New Melones. Shasta and Folsom were in flood control.

Weather and Other Conditions As of March 15, cumulative precipitation of the Northern Sierra Eight Station Index is at 120 percent of average for the date, and 103 percent of the water year average. The April 1, 2016 forecast is "below normal" for both the dry (90 percent) and most probable (50 percent) exceedence cases.

Upper Great Plains Region

Lake/Reservoir Content As of April 25, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 81.8 percent and 79.1 percent full, respectively.

Weather and Other Conditions The March actual system runoff was 59 percent of normal above Sioux City. Temperatures have been above normal this spring throughout the upper Midwest, but some late spring snowfall helped increase the snowpack numbers from the month before. As of April 1, snowpack was at 97 percent above Fort Peck and 89 percent on the reach from Fort Peck to Garrison.

Note: The Upper Great Plains Region (UGPR) reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation. Asterisks indicate that actual data is not available for the month.

WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT MAY 2016

Agency-wide Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1,434,895 1,538,279 1,966,014 1,612,157 265,079 $13,412,993 $10,002,458 $7,273,130 Nov 15 1,378,403 1,448,916 1,852,469 1,385,316 416,430 $16,197,285 $14,195,619 $9,530,629 Dec 15 1,325,629 1,506,717 1,755,293 1,497,975 492,619 $19,371,552 $13,648,145 $10,145,106 Jan 16 1,709,435 1,760,027 1,882,890 1,735,645 273,084 $9,493,892 $5,902,813 $6,561,179 Feb 16 1,365,511 1,491,899 1,746,941 1,516,513 379,479 $12,320,267 $8,662,264 $7,673,322 Mar 16 1,696,021 1,715,754 1,987,844 1,769,248 360,003 $9,989,905 $8,226,674 $6,897,196 Apr 16 1,811,037 1,901,810 2,228,272 1,872,005 May 16 Jun 16 Jul 16 Aug 16 Sep 16 Total 10,720,931 11,363,400 13,419,723 11,388,858 2,186,693 $80,785,895 $60,637,973 $48,080,562 Actual generation as a percentage of average: 84.9% Cost per MWh: $21.99

Western Area Power Administration (WAPA) generated a total of 11,389 gigawatt-hours (GWh) during October through April of fiscal year 2016, or 84.9 percent of the average. Actual purchase power data is currently available from October through March for all of WAPA’s Regions, and during this period total purchase power was 2,187 GWh and total purchase power expenses were $48,080,562, which equates to $21.99 per MWh.

The following pages indicate WAPA’s Regional snowpack, lake/reservoir inflow and content, generation, and purchase power expenses, among other things. Snowpack is reported as snow water equivalent, which is the depth of water that theoretically would result if the entire snowpack is melted instantaneously.

Colorado River Storage Project

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 0.20 0.80 514.42 535.00 15.01 12.29 248,012 340,194 382,430 379,732 71,798 $6,704,081 $2,989,589 $2,100,360 Nov 15 1.80 3.90 474.23 421.00 14.91 11.93 230,952 316,064 388,155 340,308 106,233 $7,549,826 $4,237,967 $2,748,918 Dec 15 4.00 7.90 362.96 294.00 14.86 11.54 270,310 443,456 437,962 472,018 38,014 $7,692,571 $1,952,432 $1,129,176 Jan 16 11.50 11.20 361.45 300.00 14.98 11.33 355,138 441,000 457,394 481,075 35,898 $4,412,679 $619,112 $1,067,937 Feb 16 15.10 13.40 392.01 396.00 15.99 11.22 265,647 347,936 390,580 400,465 51,902 $5,024,221 $1,432,878 $1,531,914 Mar 16 18.90 17.10 666.27 553.00 16.77 11.02 272,465 293,073 390,170 355,405 110,494 $5,517,603 $2,975,893 $2,915,399 Apr 16 19.40 17.50 1,057.14 814.00 16.74 11.01 250,695 277,986 397,861 382,353 33,650 $3,468,325 $1,850,278 $606,969 May 16 Jun 16 Jul 16 Aug 16 Sep 16 Total 1,893,220 2,459,709 2,844,551 2,811,356 447,989 $40,369,305 $16,058,149 $12,100,673 Actual generation as a percentage of average: 98.8% Cost per MWh: $27.01

Lake/Reservoir Levels Lake Powell’s elevation was 3,592 feet at the end of April, about 108 feet below the maximum reservoir level and about 102 feet above the minimum generation level. Current storage volume for Lake Powell is 11,105,000 acre-feet, which is about 45 percent of capacity.

Weather and Other Conditions No unusual conditions reported.

Desert Southwest Region

Lake/Reservoir Levels Lake Mead’s elevation was 1,076 feet at the end of April, about 143 feet below full storage level and about 26 feet above the minimum generation level.

Rocky Mountain Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 138.60 117.70 3.85 4.44 86,700 86,400 84,083 86,111 77,092 $2,329,286 $2,339,186 $2,077,078 Nov 15 120.30 107.00 3.85 4.44 65,000 65,300 81,138 65,774 78,992 $3,053,655 $3,043,755 $1,996,381 Dec 15 246.40 205.10 98.80 98.40 3.82 4.42 105,900 106,200 103,195 107,384 64,146 $2,202,853 $2,192,953 $1,620,872 Jan 16 417.90 393.40 96.20 101.70 3.80 4.41 127,800 128,400 113,267 126,958 28,770 $1,476,948 $1,463,748 $697,853 Feb 16 849.60 818.20 95.00 110.00 3.80 4.44 118,200 120,600 101,392 113,311 22,942 $620,631 $544,731 $593,731 Mar 16 1,065.10 1,012.90 158.40 145.20 3.83 4.49 134,300 155,500 120,394 117,455 20,003 $493,482 $0 $432,138 Apr 16 1,341.70 1,422.60 253.10 339.90 3.85 4.71 140,800 169,700 140,578 119,364 60,407 $1,174,107 $217,107 $959,741 May 16 Jun 16 Jul 16 Aug 16 Sep 16 Total 778,700 832,100 744,047 736,357 352,352 $11,350,962 $9,801,480 $8,377,794 Actual generation as a percentage of average: 99.0% Cost per MWh: $23.78

Lake/Reservoir Content The overall reservoir content at the end of April was 122 percent of average.

Weather and Other Conditions The Loveland Area Projects (LAP) area is drought free except for a small part of the Bighorn Basin. The snowpack is above average for the Colorado-Big Thompson Project and North Platte Basin, and has improved but is still below average in the Bighorn Basin. The latest National Weather Service forecast indicates June through August temperatures and precipitation are both more likely to be above normal in the LAP area. The spring snow melt runoff is forecast to be above average in all three basins.

Note: The Rocky Mountain Region’s (RMR) most recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 316.00 204.00 5.29 2.34 91,000 136,000 163,000 128,332 56,293 $1,820,820 $1,820,820 $1,871,992 Nov 15 3.57 2.00 386.00 210.00 5.24 2.21 79,000 99,000 104,000 38,675 57,583 $1,727,548 $1,727,548 $1,877,190 Dec 15 9.43 10.00 1,017.00 553.00 5.76 2.47 64,000 54,000 143,000 47,723 61,018 $1,803,740 $1,803,740 $1,949,075 Jan 16 17.70 20.00 1,032.00 1,653.00 6.18 3.96 15,000 0 163,000 6,638 63,436 $1,393,030 $1,393,030 $1,846,712 Feb 16 24.71 21.00 1,017.00 1,084.00 6.72 4.69 15,000 5,000 195,000 19,879 57,780 $1,309,570 $1,309,570 $1,615,090 Mar 16 27.91 24.00 1,455.00 2,955.00 7.45 6.62 30,000 75,000 207,000 162,709 47,458 $1,399,243 $1,399,243 $1,560,088 Apr 16 22.03 13.00 1,272.00 1,208.00 7.86 7.18 135,000 230,000 288,000 192,803 43,336 $659,936 $659,936 $889,087 May 16 Jun 16 Jul 16 Aug 16 Sep 16 Total 429,000 599,000 1,263,000 596,758 386,904 $10,113,887 $10,113,887 $11,609,234 Actual generation as a percentage of average: 47.2% Cost per MWh: $30.01

Lake/Reservoir Content As of April 30, accumulated inflow for the water year was 143 percent of the 15-year average for Trinity, 116 percent for Shasta, 124 percent for Folsom and 115 percent for New Melones. Reservoir storage as of the same date was 80 percent of 15-year average for Trinity, 111 percent for Shasta, 113 percent for Folsom and 42 percent for New Melones.

Weather and Other Conditions As of April 30, cumulative precipitation of the Northern Sierra Eight Station Index was at 116 percent of average for the date, and 109 percent of the water year average. The May 1, 2016 forecast for the 50 percent exceedence case is the basis for the official year type declaration, which is "below normal" for this water year.

Upper Great Plains Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1.20 0.40 8,092.00 5,998.12 55.94 59.52 669,483 656,625 956,575 698,445 58,791 $2,558,807 $2,815,967 $1,186,804 Nov 15 3.80 2.90 7,411.00 5,642.70 54.83 58.73 691,201 630,517 915,920 609,747 173,486 $3,840,879 $5,054,569 $2,903,732 Dec 15 7.10 7.00 6,468.00 5,109.00 54.23 58.41 597,319 592,071 697,821 552,796 327,646 $7,428,458 $7,533,428 $5,385,348 Jan 16 10.30 9.50 6,658.00 6,634.00 53.94 57.73 851,947 847,187 751,422 779,523 143,984 $2,211,235 $2,306,445 $2,913,693 Feb 16 12.90 11.50 6,291.00 6,046.50 54.25 58.30 632,165 631,703 668,307 600,529 246,550 $5,365,845 $5,375,085 $3,921,964 Mar 16 15.80 15.00 8,226.00 5,636.40 56.02 58.46 712,756 645,556 738,328 588,632 180,582 $2,507,548 $3,851,538 $1,939,287 Apr 16 15.10 11.00 8,061.00 6,579.20 56.91 59.23 718,242 648,989 829,810 613,890 * $1,502,829 $2,887,889 * May 16 Jun 16 Jul 16 Aug 16 Sep 16 Total 4,873,112 4,652,646 5,558,184 4,443,562 1,131,039 $25,415,600 $29,824,920 $18,250,828 Actual generation as a percentage of average: 79.9% Cost per MWh: $16.14

Lake/Reservoir Content As of May 25, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 93.2 percent and 83.3 percent full, respectively.

Weather and Other Conditions The April actual system runoff was 89 percent of normal above Sioux City. Temperatures have been above normal this spring throughout the upper Midwest, and forecasts of La Nina this summer indicate the likelihood of warmer than normal conditions for the season. Snowpack peaked on April 1. As of May 1, snowpack was at 75 percent above Fort Peck and 87 percent between Fort Peck and Garrison.

Note: The Upper Great Plains Region (UGPR) reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation. Asterisks indicate that actual data is not available for the month.

6 WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT June 2016

Agency-wide Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1,434,895 1,538,279 1,966,014 1,612,157 265,079 $13,412,993 $10,002,458 $7,273,130 Nov 15 1,378,403 1,448,916 1,852,469 1,385,316 416,430 $16,197,285 $14,195,619 $9,530,629 Dec 15 1,325,629 1,506,717 1,755,293 1,497,975 492,619 $19,371,552 $13,648,145 $10,145,106 Jan 16 1,709,435 1,760,027 1,882,890 1,735,645 273,084 $9,493,892 $5,902,813 $6,561,179 Feb 16 1,365,511 1,491,899 1,746,941 1,516,513 368,677 $12,320,267 $8,662,264 $7,423,788 Mar 16 1,696,021 1,715,754 1,987,844 1,769,248 361,467 $9,989,905 $8,226,674 $6,922,281 Apr 16 1,811,037 1,901,810 2,228,272 1,872,005 272,707 $6,805,196 $5,615,210 $4,236,684 May 16 1,931,786 2,108,664 2,639,022 2,093,613 Jun 16 Jul 16 Aug 16 Sep 16 Total 12,652,718 13,472,063 16,058,745 13,482,471 2,450,062 $87,591,091 $66,253,183 $52,092,797 Actual generation as a percentage of average: 84.0% Cost per MWh: $21.26

Western Area Power Administration (WAPA) generated a total of 13,482 gigawatt-hours (GWh) during October through May of fiscal year 2016, or 84.0 percent of the average. Actual purchase power data is currently available from October through April for all of WAPA’s Regions, and during this period total purchase power was 2,450 GWh and total purchase power expenses were $52,092,797, which equates to $21.26 per MWh.

Colorado River Storage Project

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 0.20 0.80 514.42 535.00 15.01 12.29 248,012 340,194 382,430 379,732 71,798 $6,704,081 $2,989,589 $2,100,360 Nov 15 1.80 3.90 474.23 421.00 14.91 11.93 230,952 316,064 388,155 340,308 106,233 $7,549,826 $4,237,967 $2,748,918 Dec 15 4.00 7.90 362.96 294.00 14.86 11.54 270,310 443,456 437,962 472,018 38,014 $7,692,571 $1,952,432 $1,129,176 Jan 16 11.50 11.20 361.45 300.00 14.98 11.33 355,138 441,000 457,394 481,075 35,898 $4,412,679 $619,112 $1,067,937 Feb 16 15.10 13.40 392.01 396.00 15.99 11.22 265,647 347,936 390,580 400,465 51,902 $5,024,221 $1,432,878 $1,531,914 Mar 16 18.90 17.10 666.27 553.00 16.77 11.02 272,465 293,073 390,170 355,405 110,494 $5,517,603 $2,975,893 $2,915,399 Apr 16 19.40 17.50 1,057.14 814.00 16.74 11.01 250,695 277,986 397,861 382,353 33,650 $3,468,325 $1,850,278 $606,969 May 16 7.90 9.80 2,337.68 2,294.00 16.30 12.12 320,070 401,349 501,886 469,786 10,396 $2,044,585 $0 $204,590 Jun 16 Jul 16 Aug 16 Sep 16 Total 2,213,290 2,861,058 3,346,438 3,281,142 458,385 $42,413,890 $16,058,149 $12,305,263 Actual generation as a percentage of average: 98.0% Cost per MWh: $26.84

Lake/Reservoir Levels Lake Powell’s elevation was 3,604 feet at the end of May, about 96 feet below the maximum reservoir level and about 114 feet above the minimum generation level. As of June 12, storage volume for Lake Powell was 12,814,000 acre-feet, which is about 53 percent of capacity.

Weather and Other Conditions No unusual conditions reported.

Desert Southwest Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 0.20 0.80 59.90 119.00 20.40 12.01 339,700 319,060 379,926 319,537 1,105 $0 $36,896 $36,896 Nov 15 1.80 3.90 53.51 41.00 20.44 11.95 312,250 338,035 363,256 330,812 136 $25,378 $131,780 $4,408 Dec 15 4.00 7.90 73.77 42.00 20.57 12.23 288,100 310,990 373,314 318,054 1,795 $243,930 $165,592 $60,635 Jan 16 11.50 11.20 93.00 90.00 20.71 12.52 359,550 343,440 397,807 341,451 995 $0 $120,478 $34,984 Feb 16 15.10 13.40 109.40 81.00 20.74 12.56 334,500 386,660 391,662 382,329 305 $0 $0 $10,623 Mar 16 18.90 17.10 102.88 31.00 20.54 12.32 546,500 546,625 531,952 545,047 1,466 $72,029 $0 $50,284 Apr 16 19.40 17.50 84.78 69.00 20.36 12.04 566,300 575,135 572,023 563,595 1,741 $0 $0 $59,386 May 16 7.90 9.80 59.92 51.00 20.48 11.79 526,800 475,675 572,254 481,582 8,377 $118,258 $226,470 $283,143 Jun 16 Jul 16 Aug 16 Sep 16 Total 3,273,700 3,295,620 3,582,194 3,282,407 15,920 $459,595 $681,216 $540,359 Actual generation as a percentage of average: 91.6% Cost per MWh: $33.94

Lake/Reservoir Levels Lake Mead’s elevation was 1,074 feet at the end of May, about 146 feet below full storage level and about 24 feet above the minimum generation level.

Rocky Mountain Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 138.60 117.70 3.85 4.44 86,700 86,400 84,083 86,111 77,092 $2,329,286 $2,339,186 $2,077,078 Nov 15 120.30 107.00 3.85 4.44 65,000 65,300 81,138 65,774 78,992 $3,053,655 $3,043,755 $1,996,381 Dec 15 246.40 205.10 98.80 98.40 3.82 4.42 105,900 106,200 103,195 107,384 64,146 $2,202,853 $2,192,953 $1,620,872 Jan 16 417.90 393.40 96.20 101.70 3.80 4.41 127,800 128,400 113,267 126,958 28,770 $1,476,948 $1,463,748 $697,853 Feb 16 849.60 818.20 95.00 110.00 3.80 4.44 118,200 120,600 101,392 113,311 12,140 $620,631 $544,731 $344,197 Mar 16 1,065.10 1,012.90 158.40 145.20 3.83 4.49 134,300 155,500 120,394 117,455 21,467 $493,482 $0 $457,223 Apr 16 1,341.70 1,422.60 253.10 339.90 3.85 4.71 140,800 169,700 140,578 119,364 40,028 $1,174,107 $217,107 $695,188 May 16 1,271.50 1,400.90 694.10 1,056.30 4.18 5.33 222,300 272,000 197,442 247,263 20,966 $0 $0 $457,787 Jun 16 Jul 16 Aug 16 Sep 16 Total 1,001,000 1,104,100 941,489 983,620 343,601 $11,350,962 $9,801,480 $8,346,579 Actual generation as a percentage of average: 104.5% Cost per MWh: $24.29

Lake/Reservoir Content The overall reservoir content at the end of May was 128 percent of average.

Weather and Other Conditions The Loveland Area Projects (LAP) area continues to be drought free except for parts of the Bighorn Basin. The snowpack peaked above average in the Colorado-Big Thompson Project Upper Colorado River Headwaters and in the North Platte River Basin, and while the peak snowpack in the Bighorn Basin was below average it nonetheless peaked well above last year. The latest National Weather Service forecast indicates June through August temperatures are more likely to be above normal, and precipitation is just as likely to be above as below normal in the LAP area.

Note: The Rocky Mountain Region’s (RMR) most recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 316.00 204.00 5.29 2.34 91,000 136,000 163,000 128,332 56,293 $1,820,820 $1,820,820 $1,871,992 Nov 15 3.57 2.00 386.00 210.00 5.24 2.21 79,000 99,000 104,000 38,675 57,583 $1,727,548 $1,727,548 $1,877,190 Dec 15 9.43 10.00 1,017.00 553.00 5.76 2.47 64,000 54,000 143,000 47,723 61,018 $1,803,740 $1,803,740 $1,949,075 Jan 16 17.70 20.00 1,032.00 1,653.00 6.18 3.96 15,000 0 163,000 6,638 63,436 $1,393,030 $1,393,030 $1,846,712 Feb 16 24.71 21.00 1,017.00 1,084.00 6.72 4.69 15,000 5,000 195,000 19,879 57,780 $1,309,570 $1,309,570 $1,615,090 Mar 16 27.91 24.00 1,455.00 2,955.00 7.45 6.62 30,000 75,000 207,000 162,709 47,458 $1,399,243 $1,399,243 $1,560,088 Apr 16 22.03 13.00 1,272.00 1,208.00 7.86 7.18 135,000 230,000 288,000 192,803 43,336 $659,936 $659,936 $889,087 May 16 25.00 2.00 1,210.00 921.00 7.83 7.01 245,000 295,000 442,000 322,579 37,097 $665,440 $665,440 $780,525 Jun 16 Jul 16 Aug 16 Sep 16 Total 674,000 894,000 1,705,000 919,338 424,001 $10,779,327 $10,779,327 $12,389,759 Actual generation as a percentage of average: 53.9% Cost per MWh: $29.22

Lake/Reservoir Content As of May 31, accumulated inflow for the water year was 129 percent of the 15-year average for Trinity, 110 percent for Shasta, 117 percent for Folsom, and 111 percent for New Melones. Reservoir storage as of the same date was 75 percent of 15-year average for Trinity, 111 percent for Shasta, 103 percent for Folsom, and 44 percent for New Melones.

Weather and Other Conditions As of May 31, cumulative precipitation of the Northern Sierra Eight Station Index was at 115 percent of average for the date, and 113 percent of the water year average. The May 1, 2016 forecast for the 50 percent exceedence case is the basis for the official year type declaration, which is "below normal" for this water year.

Upper Great Plains Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1.20 0.40 8,092.00 5,998.12 55.94 59.52 669,483 656,625 956,575 698,445 58,791 $2,558,807 $2,815,967 $1,186,804 Nov 15 3.80 2.90 7,411.00 5,642.70 54.83 58.73 691,201 630,517 915,920 609,747 173,486 $3,840,879 $5,054,569 $2,903,732 Dec 15 7.10 7.00 6,468.00 5,109.00 54.23 58.41 597,319 592,071 697,821 552,796 327,646 $7,428,458 $7,533,428 $5,385,348 Jan 16 10.30 9.50 6,658.00 6,634.00 53.94 57.73 851,947 847,187 751,422 779,523 143,984 $2,211,235 $2,306,445 $2,913,693 Feb 16 12.90 11.50 6,291.00 6,046.50 54.25 58.30 632,165 631,703 668,307 600,529 246,550 $5,365,845 $5,375,085 $3,921,964 Mar 16 15.80 15.00 8,226.00 5,636.40 56.02 58.46 712,756 645,556 738,328 588,632 180,582 $2,507,548 $3,851,538 $1,939,287 Apr 16 15.10 11.00 8,061.00 6,579.20 56.91 59.23 718,242 648,989 829,810 613,890 153,952 $1,502,829 $2,887,889 $1,986,054 May 16 6.60 4.30 9,699.00 6,872.50 58.18 61.10 617,617 664,640 925,440 572,402 * $3,150,160 $2,209,700 * Jun 16 Jul 16 Aug 16 Sep 16 Total 5,490,728 5,317,285 6,483,624 5,015,964 1,284,991 $28,565,760 $32,034,620 $20,236,882 Actual generation as a percentage of average: 77.4% Cost per MWh: $15.75

Lake/Reservoir Content As of June 20, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 100 percent and 91.2 percent full, respectively.

Weather and Other Conditions The May actual system runoff was 136 percent of normal above Sioux City. Heavy spring rains fell in the lower Missouri River valley causing increased inflows, and the rains soaked the lower basin causing continued curtailments of upstream hydro generation. The increased runoff will not provide more generation this year but will maintain full reservoir levels heading into next year. As of June 1, snowpack was at 68 percent of average above Fort Peck and 68 percent of average between Fort Peck and Garrison.

Note: The Upper Great Plains Region (UGPR) reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation. Asterisks indicate that actual data is not available for the month.

6 WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT July 2016

Agency-wide Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1,434,895 1,538,279 1,966,014 1,612,146 265,079 $13,412,993 $10,002,458 $7,273,130 Nov 15 1,378,403 1,448,916 1,852,469 1,385,304 416,430 $16,197,285 $14,195,619 $9,530,629 Dec 15 1,325,629 1,506,717 1,755,293 1,497,963 492,619 $19,371,552 $13,648,145 $10,145,106 Jan 16 1,709,435 1,760,027 1,882,890 1,735,632 273,084 $9,493,892 $5,902,813 $6,561,179 Feb 16 1,365,511 1,491,899 1,746,941 1,516,502 368,677 $12,320,267 $8,662,264 $7,423,788 Mar 16 1,696,021 1,715,754 1,987,844 1,769,235 361,467 $9,989,905 $8,226,674 $6,922,281 Apr 16 1,811,037 1,901,810 2,228,272 1,871,997 272,707 $6,805,196 $5,615,210 $4,236,684 May 16 1,931,786 2,108,664 2,639,022 2,093,597 218,141 $5,978,443 $3,101,610 $4,035,539 Jun 16 1,977,210 2,187,855 2,718,068 2,458,933 Jul 16 Aug 16 Sep 16 Total 14,629,928 15,659,918 18,776,812 15,941,308 2,668,203 $93,569,534 $69,354,792 $56,128,336 Actual generation as a percentage of average: 84.9% Cost per MWh: $21.04

Western Area Power Administration (WAPA) generated a total of 15,941 gigawatt-hours (GWh) during October through June of fiscal year 2016, or 84.9 percent of the average. Actual purchase power data is currently available from October through May for all of WAPA’s Regions, and during this period total purchase power was 2,668 GWh and total purchase power expenses were $56,128,336, which equates to $21.04 per MWh.

Colorado River Storage Project

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 0.20 0.80 514.42 535.00 15.01 12.29 248,012 340,194 382,430 379,732 71,798 $6,704,081 $2,989,589 $2,100,360 Nov 15 1.80 3.90 474.23 421.00 14.91 11.93 230,952 316,064 388,155 340,308 106,233 $7,549,826 $4,237,967 $2,748,918 Dec 15 4.00 7.90 362.96 294.00 14.86 11.54 270,310 443,456 437,962 472,018 38,014 $7,692,571 $1,952,432 $1,129,176 Jan 16 11.50 11.20 361.45 300.00 14.98 11.33 355,138 441,000 457,394 481,075 35,898 $4,412,679 $619,112 $1,067,937 Feb 16 15.10 13.40 392.01 396.00 15.99 11.22 265,647 347,936 390,580 400,465 51,902 $5,024,221 $1,432,878 $1,531,914 Mar 16 18.90 17.10 666.27 553.00 16.77 11.02 272,465 293,073 390,170 355,405 110,494 $5,517,603 $2,975,893 $2,915,399 Apr 16 19.40 17.50 1,057.14 814.00 16.74 11.01 250,695 277,986 397,861 382,353 33,650 $3,468,325 $1,850,278 $606,969 May 16 7.90 9.80 2,337.68 2,294.00 16.30 12.12 320,070 401,349 501,886 469,786 10,396 $2,044,585 $0 $204,590 Jun 16 0.00 0.90 2,668.50 2,907.00 16.00 13.76 337,289 476,473 585,467 543,789 0 $2,301,440 $0 $0 Jul 16 Aug 16 Sep 16 Total 2,550,579 3,337,531 3,931,905 3,824,931 458,385 $44,715,330 $16,058,149 $12,305,263 Actual generation as a percentage of average: 97.3% Cost per MWh: $26.84

Lake/Reservoir Levels Lake Powell’s elevation was 3,620 feet at the end of June, about 80 feet below the maximum reservoir level and about 130 feet above the minimum generation level. As of July 11, storage volume for Lake Powell was 13,909,000 acre-feet, which is about 57 percent of capacity.

Weather and Other Conditions No unusual conditions reported.

Desert Southwest Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 0.20 0.80 59.90 119.00 20.40 12.01 339,700 319,060 379,926 319,537 1,105 $0 $36,896 $36,896 Nov 15 1.80 3.90 53.51 41.00 20.44 11.95 312,250 338,035 363,256 330,812 136 $25,378 $131,780 $4,408 Dec 15 4.00 7.90 73.77 42.00 20.57 12.23 288,100 310,990 373,314 318,054 1,795 $243,930 $165,592 $60,635 Jan 16 11.50 11.20 93.00 90.00 20.71 12.52 359,550 343,440 397,807 341,451 995 $0 $120,478 $34,984 Feb 16 15.10 13.40 109.40 81.00 20.74 12.56 334,500 386,660 391,662 382,329 305 $0 $0 $10,623 Mar 16 18.90 17.10 102.88 31.00 20.54 12.32 546,500 546,625 531,952 545,047 1,466 $72,029 $0 $50,284 Apr 16 19.40 17.50 84.78 69.00 20.36 12.04 566,300 575,135 572,023 563,595 1,741 $0 $0 $59,386 May 16 7.90 9.80 59.92 51.00 20.48 11.79 526,800 475,675 572,254 481,582 8,377 $118,258 $226,470 $283,143 Jun 16 0.00 0.90 26.60 15.00 20.69 11.67 461,050 472,185 538,244 479,488 12,982 $354,423 $352,116 $459,822 Jul 16 Aug 16 Sep 16 Total 3,734,750 3,767,805 4,120,438 3,761,895 28,902 $814,018 $1,033,332 $1,000,181 Actual generation as a percentage of average: 91.3% Cost per MWh: $34.61

Lake/Reservoir Levels Lake Mead’s elevation was 1,072 feet at the end of June, about 148 feet below full storage level and about 22 feet above the minimum generation level.

Rocky Mountain Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 138.60 117.70 3.85 4.44 86,700 86,400 84,083 86,111 77,092 $2,329,286 $2,339,186 $2,077,078 Nov 15 120.30 107.00 3.85 4.44 65,000 65,300 81,138 65,774 78,992 $3,053,655 $3,043,755 $1,996,381 Dec 15 246.40 205.10 98.80 98.40 3.82 4.42 105,900 106,200 103,195 107,384 64,146 $2,202,853 $2,192,953 $1,620,872 Jan 16 417.90 393.40 96.20 101.70 3.80 4.41 127,800 128,400 113,267 126,958 28,770 $1,476,948 $1,463,748 $697,853 Feb 16 849.60 818.20 95.00 110.00 3.80 4.44 118,200 120,600 101,392 113,311 12,140 $620,631 $544,731 $344,197 Mar 16 1,065.10 1,012.90 158.40 145.20 3.83 4.49 134,300 155,500 120,394 117,455 21,467 $493,482 $0 $457,223 Apr 16 1,341.70 1,422.60 253.10 339.90 3.85 4.71 140,800 169,700 140,578 119,364 40,028 $1,174,107 $217,107 $695,188 May 16 1,271.50 1,400.90 694.10 1,056.30 4.18 5.33 222,300 272,000 197,442 247,263 20,966 $0 $0 $457,787 Jun 16 301.50 464.80 1,105.70 1,388.30 4.74 5.82 205,800 269,500 242,477 316,354 20,128 $172,095 $0 $534,993 Jul 16 Aug 16 Sep 16 Total 1,206,800 1,373,600 1,183,966 1,299,974 363,729 $11,523,057 $9,801,480 $8,881,572 Actual generation as a percentage of average: 109.8% Cost per MWh: $24.42

Lake/Reservoir Content The overall reservoir content at the end of June was 123 percent of average.

Weather and Other Conditions The Loveland Area Projects (LAP) area continues to be drought free except for parts of the Bighorn Basin. The spring reservoir inflow was above average across the LAP area and well above average in the North Platte River basin. The LAP reservoir storage at the end of June was above average in all three basins with gains since the end of last June. The latest National Weather Service forecast indicates August through October temperatures are more likely to be above normal and precipitation is just as likely to be above as below normal in the LAP area.

Note: The Rocky Mountain Region’s (RMR) most recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 316.00 204.00 5.29 2.34 91,000 136,000 163,000 128,332 56,293 $1,820,820 $1,820,820 $1,871,992 Nov 15 3.57 2.00 386.00 210.00 5.24 2.21 79,000 99,000 104,000 38,675 57,583 $1,727,548 $1,727,548 $1,877,190 Dec 15 9.43 10.00 1,017.00 553.00 5.76 2.47 64,000 54,000 143,000 47,723 61,018 $1,803,740 $1,803,740 $1,949,075 Jan 16 17.70 20.00 1,032.00 1,653.00 6.18 3.96 15,000 0 163,000 6,638 63,436 $1,393,030 $1,393,030 $1,846,712 Feb 16 24.71 21.00 1,017.00 1,084.00 6.72 4.69 15,000 5,000 195,000 19,879 57,780 $1,309,570 $1,309,570 $1,615,090 Mar 16 27.91 24.00 1,455.00 2,955.00 7.45 6.62 30,000 75,000 207,000 162,709 47,458 $1,399,243 $1,399,243 $1,560,088 Apr 16 22.03 13.00 1,272.00 1,208.00 7.86 7.18 135,000 230,000 288,000 192,803 43,336 $659,936 $659,936 $889,087 May 16 25.00 2.00 1,210.00 921.00 7.83 7.01 245,000 295,000 442,000 322,579 37,097 $665,440 $665,440 $780,525 Jun 16 0.00 0.00 749.00 537.00 7.38 6.54 280,000 320,000 440,000 353,394 39,345 $659,936 $659,936 $800,734 Jul 16 Aug 16 Sep 16 Total 954,000 1,214,000 2,145,000 1,272,732 463,347 $11,439,263 $11,439,263 $13,190,493 Actual generation as a percentage of average: 59.3% Cost per MWh: $28.47

Lake/Reservoir Content As of June 30, accumulated inflow for the water year was 119 percent of 15-year average for Trinity, 107 percent for Shasta, 113 percent for Folsom, and 107 percent for New Melones. Reservoir storage as of the same date was 71 percent of the 15-year average for Trinity, 114 percent for Shasta, 97 percent for Folsom, and remained at 44 percent for New Melones.

Weather and Other Conditions As of June 30, cumulative precipitation of the Northern Sierra Eight Station Index was at 115 percent of average for the date, and 116 percent of the water year average. The May 1, 2016 forecast for the 50 percent exceedence case is the basis for the official year type declaration, which is "below normal" for this water year.

Upper Great Plains Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1.20 0.40 8,092.00 5,998.12 55.94 59.52 669,483 656,625 956,575 698,434 58,791 $2,558,807 $2,815,967 $1,186,804 Nov 15 3.80 2.90 7,411.00 5,642.70 54.83 58.73 691,201 630,517 915,920 609,735 173,486 $3,840,879 $5,054,569 $2,903,732 Dec 15 7.10 7.00 6,468.00 5,109.00 54.23 58.41 597,319 592,071 697,821 552,784 327,646 $7,428,458 $7,533,428 $5,385,348 Jan 16 10.30 9.50 6,658.00 6,634.00 53.94 57.73 851,947 847,187 751,422 779,510 143,984 $2,211,235 $2,306,445 $2,913,693 Feb 16 12.90 11.50 6,291.00 6,046.50 54.25 58.30 632,165 631,703 668,307 600,518 246,550 $5,365,845 $5,375,085 $3,921,964 Mar 16 15.80 15.00 8,226.00 5,636.40 56.02 58.46 712,756 645,556 738,328 588,619 180,582 $2,507,548 $3,851,538 $1,939,287 Apr 16 15.10 11.00 8,061.00 6,579.20 56.91 59.23 718,242 648,989 829,810 613,882 153,952 $1,502,829 $2,887,889 $1,986,054 May 16 6.60 4.30 9,699.00 6,872.50 58.18 61.10 617,617 664,640 925,440 572,386 141,305 $3,150,160 $2,209,700 $2,309,494 Jun 16 0.60 0.00 11,819.00 7,634.60 60.38 67.92 693,071 649,697 911,880 765,908 * $2,485,887 $3,353,377 * Jul 16 Aug 16 Sep 16 Total 6,183,799 5,966,982 7,395,504 5,781,776 1,426,296 $31,051,647 $35,387,997 $22,546,376 Actual generation as a percentage of average: 78.2% Cost per MWh: $15.81

Lake/Reservoir Content As of July 19, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 95.2 percent and 92.6 percent full, respectively.

Weather and Other Conditions The wet spring has given way to drier conditions, and the June actual system runoff was 74 percent of normal above Sioux City.

Note: The Upper Great Plains Region (UGPR) reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation. Asterisks indicate that actual data is not available for the month.

6 WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT August 2016

Agency-wide Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1,434,895 1,538,279 1,966,014 1,612,146 261,540 $13,412,993 $10,002,458 $7,167,945 Nov 15 1,378,403 1,448,916 1,852,469 1,385,304 412,848 $16,197,285 $14,195,619 $9,444,682 Dec 15 1,325,629 1,506,717 1,755,293 1,497,963 492,619 $19,371,552 $13,648,145 $10,145,106 Jan 16 1,709,435 1,760,027 1,882,890 1,735,632 273,084 $9,493,892 $5,902,813 $6,561,179 Feb 16 1,365,511 1,491,899 1,746,941 1,516,502 368,677 $12,320,267 $8,662,264 $7,375,098 Mar 16 1,696,021 1,715,754 1,987,844 1,769,235 332,183 $9,989,905 $8,226,674 $6,512,520 Apr 16 1,811,037 1,901,810 2,228,272 1,871,997 272,707 $6,805,196 $5,615,210 $4,236,418 May 16 1,931,786 2,108,664 2,639,022 2,093,597 216,314 $5,978,443 $3,101,610 $4,016,932 Jun 16 1,977,210 2,187,855 2,718,068 2,458,933 113,816 $5,973,780 $4,365,429 $2,613,101 Jul 16 2,254,628 2,372,142 2,951,134 2,568,745 Aug 16 Sep 16 Total 16,884,556 18,032,059 21,727,947 18,510,053 2,743,788 $99,543,314 $73,720,221 $58,072,981 Actual generation as a percentage of average: 85.2% Cost per MWh: $21.17

Western Area Power Administration (WAPA) generated a total of 18,510 gigawatt-hours (GWh) during October through July of fiscal year 2016, or 85.2 percent of the average. Actual purchase power data is currently available from October through June for all of WAPA’s Regions, and during this period total purchase power was 2,744 GWh and total purchase power expenses were $58,072,981, which equates to $21.17 per MWh.

Colorado River Storage Project

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 0.20 0.80 514.42 535.00 15.01 12.29 248,012 340,194 382,430 379,732 71,798 $6,704,081 $2,989,589 $2,100,360 Nov 15 1.80 3.90 474.23 421.00 14.91 11.93 230,952 316,064 388,155 340,308 106,233 $7,549,826 $4,237,967 $2,748,918 Dec 15 4.00 7.90 362.96 294.00 14.86 11.54 270,310 443,456 437,962 472,018 38,014 $7,692,571 $1,952,432 $1,129,176 Jan 16 11.50 11.20 361.45 300.00 14.98 11.33 355,138 441,000 457,394 481,075 35,898 $4,412,679 $619,112 $1,067,937 Feb 16 15.10 13.40 392.01 396.00 15.99 11.22 265,647 347,936 390,580 400,465 51,902 $5,024,221 $1,432,878 $1,531,914 Mar 16 18.90 17.10 666.27 553.00 16.77 11.02 272,465 293,073 390,170 355,405 110,494 $5,517,603 $2,975,893 $2,915,399 Apr 16 19.40 17.50 1,057.14 814.00 16.74 11.01 250,695 277,986 397,861 382,353 33,650 $3,468,325 $1,850,278 $606,969 May 16 7.90 9.80 2,337.68 2,294.00 16.30 12.12 320,070 401,349 501,886 469,786 10,396 $2,044,585 $0 $204,590 Jun 16 0.00 0.90 2,668.50 2,907.00 16.00 13.76 337,289 476,473 585,467 543,789 0 $2,301,440 $0 $0 Jul 16 1,093.88 595.00 15.88 13.58 436,357 508,082 612,093 604,720 88 $708,807 $0 $1,647 Aug 16 Sep 16 Total 2,986,936 3,845,613 4,543,998 4,429,651 458,473 $45,424,137 $16,058,149 $12,306,910 Actual generation as a percentage of average: 97.5% Cost per MWh: $26.84

Lake/Reservoir Levels Lake Powell’s elevation was 3,618 feet at the end of July, about 82 feet below the maximum reservoir level and about 128 feet above the minimum generation level. As of August 10, the storage volume for Lake Powell was 13,448,000 acre-feet, which is about 55 percent of capacity.

Weather and Other Conditions No unusual conditions reported.

Desert Southwest Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 0.20 0.80 59.90 119.00 20.40 12.01 339,700 319,060 379,926 319,537 1,105 $0 $36,896 $36,896 Nov 15 1.80 3.90 53.51 41.00 20.44 11.95 312,250 338,035 363,256 330,812 136 $25,378 $131,780 $4,408 Dec 15 4.00 7.90 73.77 42.00 20.57 12.23 288,100 310,990 373,314 318,054 1,795 $243,930 $165,592 $60,635 Jan 16 11.50 11.20 93.00 90.00 20.71 12.52 359,550 343,440 397,807 341,451 995 $0 $120,478 $34,984 Feb 16 15.10 13.40 109.40 81.00 20.74 12.56 334,500 386,660 391,662 382,329 305 $0 $0 $10,623 Mar 16 18.90 17.10 102.88 31.00 20.54 12.32 546,500 546,625 531,952 545,047 1,466 $72,029 $0 $50,284 Apr 16 19.40 17.50 84.78 69.00 20.36 12.04 566,300 575,135 572,023 563,595 1,741 $0 $0 $59,386 May 16 7.90 9.80 59.92 51.00 20.48 11.79 526,800 475,675 572,254 481,582 8,377 $118,258 $226,470 $283,143 Jun 16 0.00 0.90 26.60 15.00 20.69 11.67 461,050 472,185 538,244 479,488 12,982 $354,423 $352,116 $459,822 Jul 16 0.00 0.90 66.04 71.00 20.59 11.74 442,200 437,695 549,987 436,658 19,303 $753,146 $695,161 $768,259 Aug 16 Sep 16 Total 4,176,950 4,205,500 4,670,425 4,198,554 48,205 $1,567,164 $1,728,493 $1,768,440 Actual generation as a percentage of average: 89.9% Cost per MWh: $36.69

Lake/Reservoir Levels Lake Mead’s elevation was 1,073 feet at the end of July, about 147 feet below full storage level and about 23 feet above the minimum generation level.

Rocky Mountain Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 138.60 117.70 3.85 4.44 86,700 86,400 84,083 86,111 73,553 $2,329,286 $2,339,186 $1,971,893 Nov 15 120.30 107.00 3.85 4.44 65,000 65,300 81,138 65,774 75,410 $3,053,655 $3,043,755 $1,910,434 Dec 15 246.40 205.10 98.80 98.40 3.82 4.42 105,900 106,200 103,195 107,384 64,146 $2,202,853 $2,192,953 $1,620,872 Jan 16 417.90 393.40 96.20 101.70 3.80 4.41 127,800 128,400 113,267 126,958 28,770 $1,476,948 $1,463,748 $697,853 Feb 16 849.60 818.20 95.00 110.00 3.80 4.44 118,200 120,600 101,392 113,311 12,140 $620,631 $544,731 $295,507 Mar 16 1,065.10 1,012.90 158.40 145.20 3.83 4.49 134,300 155,500 120,394 117,455 -7,817 $493,482 $0 $47,462 Apr 16 1,341.70 1,422.60 253.10 339.90 3.85 4.71 140,800 169,700 140,578 119,364 40,028 $1,174,107 $217,107 $694,922 May 16 1,271.50 1,400.90 694.10 1,056.30 4.18 5.33 222,300 272,000 197,442 247,263 19,139 $0 $0 $439,180 Jun 16 301.50 464.80 1,105.70 1,388.30 4.74 5.82 205,800 269,500 242,477 316,354 20,861 $172,095 $0 $606,406 Jul 16 521.10 290.10 4.45 5.35 233,700 268,000 255,437 246,991 41,650 $934,923 $0 $1,311,052 Aug 16 Sep 16 Total 1,440,500 1,641,600 1,439,403 1,546,965 367,880 $12,457,980 $9,801,480 $9,595,581 Actual generation as a percentage of average: 107.5% Cost per MWh: $26.08

Lake/Reservoir Content The overall reservoir content at the end of July was 120 percent of average.

Weather and Other Conditions The Loveland Area Projects (LAP) area remains mostly drought free, with small areas in the Bighorn River and lower North Platte River basins now considered to be in drought status. The spring reservoir inflow was above average across the LAP area and well above average in the North Platte River basin. The LAP reservoir storage at the end of July was above average in all three basins and, overall, the same as at the end of last July. The latest National Weather Service forecast indicates September through November temperatures are more likely to be above normal and precipitation is just as likely to be above as below normal in the LAP area.

Note: The Rocky Mountain Region’s (RMR) most recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 316.00 204.00 5.29 2.34 91,000 136,000 163,000 128,332 56,293 $1,820,820 $1,820,820 $1,871,992 Nov 15 3.57 2.00 386.00 210.00 5.24 2.21 79,000 99,000 104,000 38,675 57,583 $1,727,548 $1,727,548 $1,877,190 Dec 15 9.43 10.00 1,017.00 553.00 5.76 2.47 64,000 54,000 143,000 47,723 61,018 $1,803,740 $1,803,740 $1,949,075 Jan 16 17.70 20.00 1,032.00 1,653.00 6.18 3.96 15,000 0 163,000 6,638 63,436 $1,393,030 $1,393,030 $1,846,712 Feb 16 24.71 21.00 1,017.00 1,084.00 6.72 4.69 15,000 5,000 195,000 19,879 57,780 $1,309,570 $1,309,570 $1,615,090 Mar 16 27.91 24.00 1,455.00 2,955.00 7.45 6.62 30,000 75,000 207,000 162,709 47,458 $1,399,243 $1,399,243 $1,560,088 Apr 16 22.03 13.00 1,272.00 1,208.00 7.86 7.18 135,000 230,000 288,000 192,803 43,336 $659,936 $659,936 $889,087 May 16 25.00 2.00 1,210.00 921.00 7.83 7.01 245,000 295,000 442,000 322,579 37,097 $665,440 $665,440 $780,525 Jun 16 749.00 537.00 7.38 6.54 280,000 320,000 440,000 353,394 39,345 $659,936 $659,936 $800,734 Jul 16 432.00 353.00 6.57 5.76 290,000 315,000 524,000 422,571 37,314 $1,112,590 $1,112,590 $1,114,377 Aug 16 Sep 16 Total 1,244,000 1,529,000 2,669,000 1,695,303 500,661 $12,551,853 $12,551,853 $14,304,870 Actual generation as a percentage of average: 63.5% Cost per MWh: $28.57

Lake/Reservoir Content As of July 31, accumulated inflow for the water year was 116 percent of 15-year average for Trinity, 106 percent for Shasta, 112 percent for Folsom, and 105 percent for New Melones. Reservoir storage as of the same date was 69 percent of the 15-year average for Trinity, 120 percent for Shasta, 81 percent for Folsom, and 43 percent for New Melones.

Weather and Other Conditions As of July 31, cumulative precipitation of the Northern Sierra Eight Station Index was at 115 percent of average for the date, and 115 percent of the water year average. The May 1, 2016 forecast for the 50 percent exceedence case is the basis for the official year type declaration, which is "below normal" for this water year.

Upper Great Plains Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1.20 0.40 8,092.00 5,998.12 55.94 59.52 669,483 656,625 956,575 698,434 58,791 $2,558,807 $2,815,967 $1,186,804 Nov 15 3.80 2.90 7,411.00 5,642.70 54.83 58.73 691,201 630,517 915,920 609,735 173,486 $3,840,879 $5,054,569 $2,903,732 Dec 15 7.10 7.00 6,468.00 5,109.00 54.23 58.41 597,319 592,071 697,821 552,784 327,646 $7,428,458 $7,533,428 $5,385,348 Jan 16 10.30 9.50 6,658.00 6,634.00 53.94 57.73 851,947 847,187 751,422 779,510 143,984 $2,211,235 $2,306,445 $2,913,693 Feb 16 12.90 11.50 6,291.00 6,046.50 54.25 58.30 632,165 631,703 668,307 600,518 246,550 $5,365,845 $5,375,085 $3,921,964 Mar 16 15.80 15.00 8,226.00 5,636.40 56.02 58.46 712,756 645,556 738,328 588,619 180,582 $2,507,548 $3,851,538 $1,939,287 Apr 16 15.10 11.00 8,061.00 6,579.20 56.91 59.23 718,242 648,989 829,810 613,882 153,952 $1,502,829 $2,887,889 $1,986,054 May 16 6.60 4.30 9,699.00 6,872.50 58.18 61.10 617,617 664,640 925,440 572,386 141,305 $3,150,160 $2,209,700 $2,309,494 Jun 16 0.60 0.00 11,819.00 7,634.60 60.38 61.91 693,071 649,697 911,880 765,908 40,628 $2,485,887 $3,353,377 $746,139 Jul 16 10,827.00 7,228.20 60.36 61.13 852,371 843,365 1,009,617 857,805 * $2,067,561 $2,247,681 * Aug 16 Sep 16 Total 7,036,170 6,810,346 8,405,120 6,639,581 1,466,924 $33,119,208 $37,635,678 $23,292,515 Actual generation as a percentage of average: 79.0% Cost per MWh: $15.88

Lake/Reservoir Content As of August 24, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 85.2 percent and 88.5 percent full, respectively.

Weather and Other Conditions The mountain snowpack melted by the end of June this year which was a couple of weeks earlier than normal, and this created below average inflows in July. The July actual system runoff was 69 percent of normal.

Note: The Upper Great Plains Region (UGPR) reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation. Asterisks indicate that actual data is not available for the month.

6 WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT September 2016

Agency-wide Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1,434,895 1,538,279 1,966,014 1,612,146 261,540 $13,412,993 $10,002,458 $7,167,945 Nov 15 1,378,403 1,448,916 1,852,469 1,385,304 412,848 $16,197,285 $14,195,619 $9,444,682 Dec 15 1,325,629 1,506,717 1,755,293 1,497,963 492,619 $19,371,552 $13,648,145 $10,145,106 Jan 16 1,709,435 1,760,027 1,882,890 1,735,632 273,084 $9,493,892 $5,902,813 $6,561,179 Feb 16 1,365,511 1,491,899 1,746,941 1,516,502 368,677 $12,320,267 $8,662,264 $7,375,098 Mar 16 1,696,021 1,715,754 1,987,844 1,769,235 332,183 $9,989,905 $8,226,674 $6,512,520 Apr 16 1,811,037 1,901,810 2,228,272 1,871,997 261,063 $6,805,196 $5,615,210 $3,974,380 May 16 1,931,786 2,108,664 2,639,022 2,093,597 207,284 $5,978,443 $3,101,610 $3,824,730 Jun 16 1,977,210 2,187,855 2,718,068 2,458,933 113,816 $5,973,780 $4,365,429 $2,613,101 Jul 16 2,254,628 2,372,142 2,951,134 2,568,745 124,870 $5,577,027 $4,055,432 $3,673,660 Aug 16 2,126,275 2,195,698 2,730,139 2,318,352 Sep 16 Total 19,010,831 20,227,757 24,458,086 20,828,405 2,847,984 $105,120,342 $77,775,653 $61,292,401 Actual generation as a percentage of average: 85.2% Cost per MWh: $21.52

Western Area Power Administration (WAPA) generated a total of 20,828 gigawatt-hours (GWh) during October through August of fiscal year 2016, or 85.2 percent of the average. Actual purchase power data is currently available from October through July for all of WAPA’s Regions, and during this period total purchase power was 2,848 GWh and total purchase power expenses were $61,292,401, which equates to $21.52 per MWh.

Colorado River Storage Project

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 0.20 0.80 514.42 535.00 15.01 12.29 248,012 340,194 382,430 379,732 71,798 $6,704,081 $2,989,589 $2,100,360 Nov 15 1.80 3.90 474.23 421.00 14.91 11.93 230,952 316,064 388,155 340,308 106,233 $7,549,826 $4,237,967 $2,748,918 Dec 15 4.00 7.90 362.96 294.00 14.86 11.54 270,310 443,456 437,962 472,018 38,014 $7,692,571 $1,952,432 $1,129,176 Jan 16 11.50 11.20 361.45 300.00 14.98 11.33 355,138 441,000 457,394 481,075 35,898 $4,412,679 $619,112 $1,067,937 Feb 16 15.10 13.40 392.01 396.00 15.99 11.22 265,647 347,936 390,580 400,465 51,902 $5,024,221 $1,432,878 $1,531,914 Mar 16 18.90 17.10 666.27 553.00 16.77 11.02 272,465 293,073 390,170 355,405 110,494 $5,517,603 $2,975,893 $2,915,399 Apr 16 19.40 17.50 1,057.14 814.00 16.74 11.01 250,695 277,986 397,861 382,353 33,650 $3,468,325 $1,850,278 $606,969 May 16 7.90 9.80 2,337.68 2,294.00 16.30 12.12 320,070 401,349 501,886 469,786 10,396 $2,044,585 $0 $204,590 Jun 16 0.00 0.90 2,668.50 2,907.00 16.00 13.76 337,289 476,473 585,467 543,789 0 $2,301,440 $0 $0 Jul 16 0.00 0.90 1,093.88 595.00 15.88 13.58 436,357 508,082 612,093 604,720 88 $708,807 $0 $1,647 Aug 16 0.00 0.90 496.08 253.00 15.68 13.09 429,891 488,585 574,470 565,084 1,416 $1,004,331 $0 $26,626 Sep 16 Total 3,416,827 4,334,198 5,118,468 4,994,735 459,889 $46,428,468 $16,058,149 $12,333,536 Actual generation as a percentage of average: 97.6% Cost per MWh: $26.82

Lake/Reservoir Levels Lake Powell’s elevation was 3,614 feet at the end of August, about 86 feet below the maximum reservoir level and about 124 feet above the minimum generation level. The storage volume for Lake Powell was 13,091,000 acre-feet at the end of August, which is about 54 percent of capacity.

Weather and Other Conditions No unusual conditions reported.

Desert Southwest Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 0.20 0.80 59.90 119.00 20.40 12.01 339,700 319,060 379,926 319,537 1,105 $0 $36,896 $36,896 Nov 15 1.80 3.90 53.51 41.00 20.44 11.95 312,250 338,035 363,256 330,812 136 $25,378 $131,780 $4,408 Dec 15 4.00 7.90 73.77 42.00 20.57 12.23 288,100 310,990 373,314 318,054 1,795 $243,930 $165,592 $60,635 Jan 16 11.50 11.20 93.00 90.00 20.71 12.52 359,550 343,440 397,807 341,451 995 $0 $120,478 $34,984 Feb 16 15.10 13.40 109.40 81.00 20.74 12.56 334,500 386,660 391,662 382,329 305 $0 $0 $10,623 Mar 16 18.90 17.10 102.88 31.00 20.54 12.32 546,500 546,625 531,952 545,047 1,466 $72,029 $0 $50,284 Apr 16 19.40 17.50 84.78 69.00 20.36 12.04 566,300 575,135 572,023 563,595 1,741 $0 $0 $59,386 May 16 7.90 9.80 59.92 51.00 20.48 11.79 526,800 475,675 572,254 481,582 8,377 $118,258 $226,470 $283,143 Jun 16 0.00 0.90 26.60 15.00 20.69 11.67 461,050 472,185 538,244 479,488 12,982 $354,423 $352,116 $459,822 Jul 16 0.00 0.90 66.04 71.00 20.59 11.74 442,200 437,695 549,987 436,658 19,303 $753,146 $695,161 $768,259 Aug 16 0.00 0.90 99.79 106.00 20.46 11.88 391,150 363,910 514,205 376,935 27,002 $1,174,078 $1,174,078 $1,086,290 Sep 16 Total 4,568,100 4,569,410 5,184,630 4,575,488 75,207 $2,741,242 $2,902,571 $2,854,730 Actual generation as a percentage of average: 88.3% Cost per MWh: $37.96

Lake/Reservoir Levels Lake Mead’s elevation was 1,075 feet at the end of August, about 144 feet below full storage level and about 25 feet above the minimum generation level.

Rocky Mountain Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 138.60 117.70 3.85 4.44 86,700 86,400 84,083 86,111 73,553 $2,329,286 $2,339,186 $1,971,893 Nov 15 120.30 107.00 3.85 4.44 65,000 65,300 81,138 65,774 75,410 $3,053,655 $3,043,755 $1,910,434 Dec 15 246.40 205.10 98.80 98.40 3.82 4.42 105,900 106,200 103,195 107,384 64,146 $2,202,853 $2,192,953 $1,620,872 Jan 16 417.90 393.40 96.20 101.70 3.80 4.41 127,800 128,400 113,267 126,958 28,770 $1,476,948 $1,463,748 $697,853 Feb 16 849.60 818.20 95.00 110.00 3.80 4.44 118,200 120,600 101,392 113,311 12,140 $620,631 $544,731 $295,507 Mar 16 1,065.10 1,012.90 158.40 145.20 3.83 4.49 134,300 155,500 120,394 117,455 -7,817 $493,482 $0 $47,462 Apr 16 1,341.70 1,422.60 253.10 339.90 3.85 4.71 140,800 169,700 140,578 119,364 28,384 $1,174,107 $217,107 $432,884 May 16 1,271.50 1,400.90 694.10 1,056.30 4.18 5.33 222,300 272,000 197,442 247,263 10,109 $0 $0 $246,978 Jun 16 301.50 464.80 1,105.70 1,388.30 4.74 5.82 205,800 269,500 242,477 316,354 20,861 $172,095 $0 $606,406 Jul 16 521.10 290.10 4.45 5.35 233,700 268,000 255,437 246,991 40,377 $934,923 $0 $1,386,263 Aug 16 188.60 118.60 4.00 4.80 205,200 224,400 203,695 177,520 42,428 $196,680 $0 $1,180,209 Sep 16 Total 1,645,700 1,866,000 1,643,098 1,724,485 388,361 $12,654,660 $9,801,480 $10,396,761 Actual generation as a percentage of average: 105.0% Cost per MWh: $26.77

Lake/Reservoir Content The overall reservoir content at the end of August was 120 percent of average.

Weather and Other Conditions Drought conditions have returned to some parts of the Bighorn and Platte River basins with a more extensive area considered abnormally dry. The year to date reservoir inflow is above average across the Loveland Area Projects (LAP) area and well above average in the North Platte River basin. The LAP reservoir storage at the end of August was above average in all three basins but, overall, slightly less than at the end of last August. The latest National Weather Service forecast indicates October through December temperatures are more likely to be above normal and precipitation is just as likely to be above as below normal in the LAP area.

Note: The Rocky Mountain Region’s (RMR) most recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 316.00 204.00 5.29 2.34 91,000 136,000 163,000 128,332 56,293 $1,820,820 $1,820,820 $1,871,992 Nov 15 3.57 2.00 386.00 210.00 5.24 2.21 79,000 99,000 104,000 38,675 57,583 $1,727,548 $1,727,548 $1,877,190 Dec 15 9.43 10.00 1,017.00 553.00 5.76 2.47 64,000 54,000 143,000 47,723 61,018 $1,803,740 $1,803,740 $1,949,075 Jan 16 17.70 20.00 1,032.00 1,653.00 6.18 3.96 15,000 0 163,000 6,638 63,436 $1,393,030 $1,393,030 $1,846,712 Feb 16 24.71 21.00 1,017.00 1,084.00 6.72 4.69 15,000 5,000 195,000 19,879 57,780 $1,309,570 $1,309,570 $1,615,090 Mar 16 27.91 24.00 1,455.00 2,955.00 7.45 6.62 30,000 75,000 207,000 162,709 47,458 $1,399,243 $1,399,243 $1,560,088 Apr 16 22.03 13.00 1,272.00 1,208.00 7.86 7.18 135,000 230,000 288,000 192,803 43,336 $659,936 $659,936 $889,087 May 16 25.00 2.00 1,210.00 921.00 7.83 7.01 245,000 295,000 442,000 322,579 37,097 $665,440 $665,440 $780,525 Jun 16 749.00 537.00 7.38 6.54 280,000 320,000 440,000 353,394 39,345 $659,936 $659,936 $800,734 Jul 16 432.00 353.00 6.57 5.76 290,000 315,000 524,000 422,571 37,314 $1,112,590 $1,112,590 $1,114,377 Aug 16 344.00 308.00 5.91 5.08 210,000 240,000 402,000 333,359 45,888 $1,150,782 $1,150,782 $1,175,100 Sep 16 Total 1,454,000 1,769,000 3,071,000 2,028,662 546,549 $13,702,635 $13,702,635 $15,479,970 Actual generation as a percentage of average: 66.1% Cost per MWh: $28.32

Lake/Reservoir Content As of August 31, accumulated inflow for the water year was 116 percent of 15-year average for Trinity, 105 percent for Shasta, 112 percent for Folsom, and 105 percent for New Melones. Reservoir storage as of the same date was 69 percent of the 15-year average for Trinity, 121 percent for Shasta, 69 percent for Folsom, and 43 percent for New Melones.

Weather and Other Conditions As of August 31, cumulative precipitation of the Northern Sierra Eight Station Index was at 115 percent of average for the date, and 116 percent of the water year average. The May 1, 2016 forecast for the 50 percent exceedence case is the basis for the official year type declaration, which is "below normal" for this water year.

Upper Great Plains Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 15 1.20 0.40 8,092.00 5,998.12 55.94 59.52 669,483 656,625 956,575 698,434 58,791 $2,558,807 $2,815,967 $1,186,804 Nov 15 3.80 2.90 7,411.00 5,642.70 54.83 58.73 691,201 630,517 915,920 609,735 173,486 $3,840,879 $5,054,569 $2,903,732 Dec 15 7.10 7.00 6,468.00 5,109.00 54.23 58.41 597,319 592,071 697,821 552,784 327,646 $7,428,458 $7,533,428 $5,385,348 Jan 16 10.30 9.50 6,658.00 6,634.00 53.94 57.73 851,947 847,187 751,422 779,510 143,984 $2,211,235 $2,306,445 $2,913,693 Feb 16 12.90 11.50 6,291.00 6,046.50 54.25 58.30 632,165 631,703 668,307 600,518 246,550 $5,365,845 $5,375,085 $3,921,964 Mar 16 15.80 15.00 8,226.00 5,636.40 56.02 58.46 712,756 645,556 738,328 588,619 180,582 $2,507,548 $3,851,538 $1,939,287 Apr 16 15.10 11.00 8,061.00 6,579.20 56.91 59.23 718,242 648,989 829,810 613,882 153,952 $1,502,829 $2,887,889 $1,986,054 May 16 6.60 4.30 9,699.00 6,872.50 58.18 61.10 617,617 664,640 925,440 572,386 141,305 $3,150,160 $2,209,700 $2,309,494 Jun 16 0.60 0.00 11,819.00 7,634.60 60.38 61.91 693,071 649,697 911,880 765,908 40,628 $2,485,887 $3,353,377 $746,139 Jul 16 10,827.00 7,228.20 60.36 61.13 852,371 843,365 1,009,617 857,805 27,788 $2,067,561 $2,247,681 $403,114 Aug 16 9,829.00 6,943.40 58.77 59.69 890,035 878,803 1,035,769 865,454 * $83,271 $307,901 * Sep 16 Total 7,926,204 7,689,149 9,440,889 7,505,035 1,494,712 $33,202,478 $37,943,578 $23,695,629 Actual generation as a percentage of average: 79.5% Cost per MWh: $15.85

Lake/Reservoir Content As of September 15, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 80.4 percent and 88.6 percent full, respectively.

Weather and Other Conditions Dry conditions continued across the plains this summer, which caused below-average inflows again in August. The August actual system runoff was 76 percent of normal.

Note: The Upper Great Plains Region (UGPR) reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation. Asterisks indicate that actual data is not available for the month.

WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT January 2017

Agency-wide Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1,315,017 1,426,426 1,875,967 1,428,673 337,634 $14,667,625 $9,521,646 $8,354,594 Nov 16 1,383,358 1,355,599 1,760,441 1,390,468 455,186 $16,259,488 $12,897,315 $10,410,259 Dec 16 1,328,808 1,461,830 1,702,288 1,592,646 Jan 17 Feb 17 Mar 17 Apr 17 May 17 Jun 17 Jul 17 Aug 17 Sep 17 Total 4,027,183 4,243,855 5,338,696 4,411,788 792,820 $30,927,113 $22,418,961 $18,764,853 Actual generation as a percentage of average: 82.6% Cost per MWh: $23.67

Western Area Power Administration (WAPA) generated a total of 4,412 gigawatt-hours (GWh) during October through December of fiscal year 2017, or 82.6 percent of the average. Actual purchase power data is currently available from October through November for all of WAPA’s Regions, and during this period total purchase power was 793 GWh and total purchase power expenses were $18,764,853, which equates to $23.67 per MWh.

Colorado River Storage Project

Lake/Reservoir Levels Lake Powell’s elevation was 3,600 feet at the end of December, about 100 feet below the maximum reservoir level and about 110 feet above the minimum generation level. The storage volume for Lake Powell was 11,797,000 acre-feet at the end of December, which is about 49 percent of capacity.

Weather and Other Conditions In December and January, a number of winter storms significantly increased snowpack conditions in the Upper Colorado River Basin. Despite the improved snow conditions, inflow into Lake Powell for water year 2017 is forecasted to be 88 percent of average. However, this is a significant improvement over the December inflow forecast of 72 percent of average.

Desert Southwest Region

Lake/Reservoir Levels Lake Mead’s elevation was 1,081 feet at the end of December, about 139 feet below full storage level and about 31 feet above the minimum generation level. Lake Mead’s elevation is forecasted to peak at approximately 1,087 feet in February, and is forecasted to drop to a minimum elevation of approximately 1,072 feet in June.

Weather and Other Conditions The Desert Southwest Region’s hydrology is mostly dependent on the Colorado River Basin snowpack and precipitation above Lake Powell. The water year 2017 precipitation is currently 136 percent of average. This year’s snowpack is certainly promising. If the above-average snowpack continues, equalization releases from Lake Powell might be imposed in April 2017 which could possibly provide Lake Mead with an additional 1 to 2 million acre-feet this year.

Rocky Mountain Region

Lake/Reservoir Content The overall reservoir content at the end of December was 123 percent of average.

Weather and Other Conditions Drought conditions have improved due to recent winter storms, with merely dry conditions persisting in parts of the Loveland Area Projects (LAP) area. The snowpack has improved significantly and is well above average across the LAP area. October through December reservoir inflows were well above average in the Bighorn River Basin, below average in the Colorado River headwaters, and well below average in the Upper North Platte River Basin. The latest National Weather Service forecast indicates February through April temperatures are just as likely to be above as below normal in the LAP area. The precipitation is more likely to be above normal in the Bighorn River Basin while just as likely to be above as below normal in the North Platte and Colorado River Basins. LAP generation deficits occurred while the Colorado-Big Thompson Project (CBT) was largely unavailable from November through mid-December. No surplus generation is expected until spring, and surpluses are then projected to continue until August when CBT generation will be restricted during a Charles Hansen Feeder Canal siphon repair scheduled from August through mid-November.

Note: The Rocky Mountain Region’s (RMR) most recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Lake/Reservoir Content As of December 31, accumulated inflow for the water year was 213 percent of 15-year average for Trinity, 139 percent for Shasta, 217 percent for Folsom, and 126 percent for New Melones. Reservoir storage as of the same date was 89 percent of the 15-year average for Trinity, 128 percent for Shasta, 100 percent for Folsom, and 49 percent for New Melones. The Folsom and Shasta Reservoirs have both been spilling, with Folsom having spilled during most of the last half of December due to early snowmelt conditions.

Weather and Other Conditions As of December 31, cumulative precipitation of the Northern Sierra Eight Station Index was at 158 percent of average for the date. The January 1, 2017 forecast for the 50 percent exceedence case is "above normal" as is the 90 percent exceedence case, not reflecting recent storm events.

Note: The Sierra Nevada Region’s (SNR) average generation is based upon long-term modeling done for its "Green Book." SNR’s projected power expenses are based upon term purchases of 35 to 65 percent of projected power needs, with the difference being left to day-ahead markets after project pumping and generation have been scheduled.

Upper Great Plains Region

Lake/Reservoir Content As of January 25, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 75.0 percent and 88.5 percent full, respectively.

Weather and Other Conditions The January runoff forecast is projecting an average water year for 2017. Snowpack accumulations have increased, with 78 percent of average above Fort Peck and 104 percent of average on the Garrison to Fort Peck reach.

Note: The Upper Great Plains Region (UGPR) reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation. Asterisks indicate that actual data is not available for the month.

6 WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT February 2017

Agency-wide Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1,315,017 1,426,426 1,875,967 1,427,953 334,479 $14,667,625 $9,521,646 $8,321,897 Nov 16 1,383,358 1,355,599 1,760,441 1,389,319 435,683 $16,259,488 $12,897,315 $10,321,160 Dec 16 1,328,808 1,461,830 1,702,288 1,591,517 418,448 $18,684,123 $12,067,535 $10,681,879 Jan 17 1,491,887 1,784,763 1,873,619 1,855,506 Feb 17 Mar 17 Apr 17 May 17 Jun 17 Jul 17 Aug 17 Sep 17 Total 5,519,071 6,028,618 7,212,315 6,264,296 1,188,610 $49,611,236 $34,486,496 $29,324,936 Actual generation as a percentage of average: 86.9% Cost per MWh: $24.67

Western Area Power Administration (WAPA) generated a total of 6,264 gigawatt-hours (GWh) during October through January of fiscal year 2017, or 86.9 percent of the average. Actual purchase power data is currently available from October through December for all of WAPA’s Regions, and during this period total purchase power was 1,189 GWh and total purchase power expenses were $29,324,936, which equates to $24.67 per MWh.

Colorado River Storage Project

Lake/Reservoir Levels Lake Powell’s elevation was 3,596 feet at the end of January, about 104 feet below the maximum reservoir level and about 106 feet above the minimum generation level. The storage volume for Lake Powell was 11,359,000 acre-feet at the end of January, which is about 47 percent of capacity.

Weather and Other Conditions The upper Colorado River Basin experienced higher than average precipitation in January and the first part of February, which resulted in a significant increase of the forecasted April-July inflow into Lake Powell for water year 2017. Current projections indicate Lake Powell elevation will increase about 46 feet from the end of January elevation, which corresponds to an increase of about 4.8 million acre-feet in storage.

Desert Southwest Region

Lake/Reservoir Levels Lake Mead’s elevation was 1,086 feet at the end of January, about 134 feet below full storage level and about 36 feet above the minimum generation level. Lake Mead’s elevation is forecasted to peak at approximately 1,089 feet in February, and is forecasted to drop to a minimum elevation of approximately 1,075 feet in June.

Weather and Other Conditions The Desert Southwest Region’s hydrology is mostly dependent on the Colorado River Basin snowpack and precipitation above Lake Powell. The water year 2017 precipitation is currently 139 percent of average. This year’s snowpack is certainly promising. If the above-average snowpack continues, equalization releases from Lake Powell might be imposed in April 2017 which could possibly provide Lake Mead with an additional 1 to 2 million acre-feet this year.

Rocky Mountain Region

Lake/Reservoir Content The overall reservoir content at the end of January was 123 percent of average.

Weather and Other Conditions The snowpack remains well above average across the Loveland Area Projects (LAP) area, and none of the high-elevation areas from which LAP snowmelt originates are considered to be in drought status. The February forecasts of most probable reservoir inflows from spring runoff were well above average in all river basins. The overall LAP reservoir storage at the end of January was above average and higher than it was at this time last year. The latest National Weather Service forecast indicates March through May temperatures are more likely to be above normal in Colorado and the precipitation is more likely to be above normal in Wyoming. LAP generation deficits occurred while the Colorado-Big Thompson Project (CBT) was largely unavailable from November through mid-December. No surplus generation is expected until spring, and surpluses are then projected to continue until August when CBT generation will be restricted during a Charles Hansen Feeder Canal siphon repair scheduled from August through mid-November.

Note: The Rocky Mountain Region’s (RMR) most recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Lake/Reservoir Content As of January 31, accumulated inflow for the water year was 196 percent of the 15-year average for Trinity, 170 percent for Shasta, 329 percent for Folsom, and 239 percent for New Melones. Reservoir storage as of the same date was 97 percent of the 15-year average for Trinity, 124 percent for Shasta, 94 percent for Folsom, and 75 percent for New Melones. The Shasta and Folsom Reservoirs continue to spill for flood control, while Trinity and New Melones Reservoirs respectively gained 200 and nearly 400 thousand acre-feet in January.

Weather and Other Conditions As of January 31, cumulative precipitation of the Northern Sierra Eight Station Index was at 193 percent of average for the date. The forecast based upon February 1, 2017, for the 50 percent exceedence case is "wet" as is the 90 percent exceedence case, reflecting continuous storm events.

Upper Great Plains Region

Lake/Reservoir Content As of February 20, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 76.4 percent and 87.6 percent full, respectively.

Weather and Other Conditions A mid-month thaw in January produced an average runoff of 151 percent of average. Snowpack accumulations have increased to 83 percent of average above Fort Peck and 117 percent of average on the Garrison to Fort Peck reach.

Note: The Upper Great Plains Region (UGPR) reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation. Asterisks indicate that actual data is not available for the month.

6 WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT March 2017

Agency-wide Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1,315,017 1,426,426 1,875,969 1,427,953 334,086 $14,667,625 $9,521,646 $8,311,130 Nov 16 1,383,358 1,355,599 1,760,444 1,389,326 435,683 $16,259,488 $12,897,315 $10,321,160 Dec 16 1,328,808 1,461,830 1,702,290 1,591,771 418,448 $18,684,123 $12,067,535 $10,681,879 Jan 17 1,491,887 1,745,023 1,873,622 1,855,506 418,457 $12,363,090 $9,284,807 $10,229,253 Feb 17 1,398,791 1,649,920 1,721,646 1,734,010 Mar 17 Apr 17 May 17 Jun 17 Jul 17 Aug 17 Sep 17 Total 6,917,862 7,638,798 8,933,970 7,998,567 1,606,674 $61,974,326 $43,771,303 $39,543,422 Actual generation as a percentage of average: 89.5% Cost per MWh: $24.61

Western Area Power Administration (WAPA) generated a total of 7,999 gigawatt-hours (GWh) during October through February of fiscal year 2017, or 89.5 percent of the average. Actual purchase power data is currently available from October through January for all of WAPA’s Regions, and during this period total purchase power was 1,607 GWh and total purchase power expenses were $39,543,422, which equates to $24.61 per MWh.

Colorado River Storage Project

Lake/Reservoir Levels Lake Powell’s elevation was 3,594 feet at the end of February, about 106 feet below the maximum reservoir level and about 104 feet above the minimum generation level. The storage volume for Lake Powell was 11.2 million acre-feet (MAF) at the end of February, which is about 46 percent of capacity.

Weather and Other Conditions The upper Colorado River Basin experienced higher than average precipitation in February. The March 1 April-July inflow forecast was 145 percent of average; however, conditions have dried out in the upper Colorado River Basin and the March mid-month April-July inflow forecast was reduced to 138 percent of average.

Desert Southwest Region

Lake/Reservoir Levels Lake Mead’s elevation was 1,090 feet at the end of February, about 130 feet below full storage level and about 40 feet above the minimum generation level. Lake Mead started the water year with a minimum elevation of 1,076 feet in October and it reached a peak elevation of 1,090 feet in February.

Rocky Mountain Region

Lake/Reservoir Content The overall reservoir content at the end of February was 126 percent of average.

Weather and Other Conditions The snowpack remains well above average across the Loveland Area Projects (LAP) area even though there has been loss of lower-elevation snow due to recent warm weather, and none of the high-elevation areas from which LAP snowmelt originates are considered to be in drought status. The overall LAP reservoir storage at the end of February was above average and higher than it was at the same time last year, and the March forecasts of most probable reservoir inflows from spring runoff were well above average in all river basins. The latest National Weather Service forecast indicates April through June temperatures are more likely to be above normal in Colorado and southern Wyoming.

Note: The Rocky Mountain Region’s (RMR) most recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Lake/Reservoir Content As of February 28, accumulated inflow for the water year was 234 percent of the 15-year average for Trinity, 228 percent for Shasta, 414 percent for Folsom, and 337 percent for New Melones. Reservoir storage as of the same date was 119 percent of the 15-year average for Trinity, 119 percent for Shasta, 81 percent for Folsom, and 111 percent for New Melones. The Shasta and Folsom Reservoirs are no longer spilling for flood control, while the Trinity and New Melones Reservoirs respectively gained nearly 500 thousand acre-feet (kAF) and nearly 600 kAF in February.

Weather and Other Conditions As of February 28, cumulative precipitation of the Northern Sierra Eight Station Index was at 214 percent of average for the date. The forecast based upon March 1, 2017, for the 50 percent exceedence case is "wet" as is the 90 percent exceedence case, reflecting continuous storm events.

Upper Great Plains Region

Lake/Reservoir Content As of March 20, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 79.5 percent and 81.8 percent full, respectively. Reservoir system storage rose to 56.97 MAF, above the Base Flood Control level of 56.1 MAF.

Weather and Other Conditions Warmer weather in February melted much of the plains snowpack and produced an above-average runoff of 219 percent, with the runoff mainly originating from the lower part of the Missouri River Basin. Snowpack accumulations have increased to 97 percent of average above Fort Peck and 132 percent of average on the Garrison to Fort Peck reach.

Note: The Upper Great Plains Region (UGPR) reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation. Asterisks indicate that actual data is not available for the month.

6 WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT April 2017

Agency-wide Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1,315,017 1,426,426 1,875,969 1,427,953 334,086 $14,667,625 $9,521,646 $8,311,130 Nov 16 1,383,358 1,355,599 1,760,444 1,389,326 435,683 $16,259,488 $12,897,315 $10,321,160 Dec 16 1,328,808 1,461,830 1,702,290 1,591,771 418,448 $18,684,123 $12,067,535 $10,681,879 Jan 17 1,491,887 1,745,023 1,873,622 1,855,506 418,457 $12,363,090 $9,284,807 $10,229,253 Feb 17 1,398,791 1,649,920 1,721,646 1,734,010 461,396 $11,517,410 $7,943,048 $8,691,421 Mar 17 1,925,710 2,008,918 1,965,516 2,193,546 Apr 17 May 17 Jun 17 Jul 17 Aug 17 Sep 17 Total 8,843,572 9,647,716 10,899,486 10,192,113 2,068,070 $73,491,737 $51,714,350 $48,234,843 Actual generation as a percentage of average: 93.5% Cost per MWh: $23.32

Western Area Power Administration (WAPA) generated a total of 10,192 gigawatt-hours (GWh) during October through March of fiscal year 2017, or 93.5 percent of the average. Actual purchase power data is currently available from October through February for all of WAPA’s Regions, and during this period total purchase power was 2,068 GWh and total purchase power expenses were $48,234,843, which equates to $23.32 per MWh.

Colorado River Storage Project

Lake/Reservoir Levels Lake Powell’s elevation was 3,596 feet at the end of March, about 104 feet below the maximum reservoir level and about 106 feet above the minimum generation level. The storage volume for Lake Powell was 11.36 million acre-feet (MAF) at the end of March, which is about 47 percent of capacity.

Weather and Other Conditions The April-July inflow forecasts peaked on March 1 at 145 percent of average; however, the April 15 forecast was 123 percent of average due to drier conditions in the basin.

Desert Southwest Region

Lake/Reservoir Levels Lake Mead’s elevation was 1,088 feet at the end of March, about 131 feet below full storage level and about 138 feet above the new minimum generation level of 950 feet. Lake Mead started the water year with a minimum elevation of 1,076 feet in October and reached a peak elevation of 1,090 feet in February.

Rocky Mountain Region

Lake/Reservoir Content The overall reservoir content at the end of March was 114 percent of average.

Weather and Other Conditions None of the high-elevation areas from which Loveland Area Projects (LAP) snowmelt originates are considered to be in drought status, but the eastern plains of Colorado are considered to be in drought status. The snowpack in the Bighorn Basin remains well above average; however, the snowpack is now below average in the Upper Colorado River headwaters and the Upper North Platte River Basin due to recent warm weather. The April forecasts of most probable reservoir inflows from spring runoff is above average in the Upper Colorado River and well above average in the North Platte and Bighorn basins. The overall LAP reservoir storage at the end of March was above average and higher than it was at the same time last year. The latest National Weather Service forecast indicates May through July temperatures and precipitation are more likely to be above normal in the LAP area.

Note: The Rocky Mountain Region’s (RMR) most recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Lake/Reservoir Content As of March 31, accumulated inflow for the water year was 215 percent of the 15-year average for Trinity, 207 percent for Shasta, 351 percent for Folsom, and 311 percent for New Melones. Reservoir storage as of the same date was 123 percent of the 15-year average for Trinity, 112 percent for Shasta, 95 percent for Folsom, and 123 percent for New Melones. The Shasta and Folsom Reservoirs returned to flood control operations by the end of March, while snowpack above New Melones was forecast to exceed storage capacity by 1 MAF.

Weather and Other Conditions As of March 31, cumulative precipitation of the Northern Sierra Eight Station Index was at 192 percent of average for the date. The forecast based upon April 1, 2017, for the 50 percent exceedence case is "wet" as is the 90 percent exceedence case, reflecting continuous storm events.

Upper Great Plains Region

Lake/Reservoir Content As of April 19, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 84.0 percent and 73.3 percent full, respectively.

Weather and Other Conditions Warm weather in March continued to melt the plains snowpack which produced an above-average runoff of 111 percent, with the runoff mainly originating from the lower part of the Missouri River Basin. Snowpack accumulations are 92 percent of average above Fort Peck and 135 percent of average on the Garrison to Fort Peck reach.

Note: The Upper Great Plains Region (UGPR) reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation. Asterisks indicate that actual data is not available for the month.

6 WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT May 2017

Agency-wide Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1,315,017 1,426,426 1,875,969 1,427,953 327,454 $14,667,625 $9,521,646 $8,170,374 Nov 16 1,383,358 1,355,599 1,760,444 1,389,326 435,683 $16,259,488 $12,897,315 $10,321,160 Dec 16 1,328,808 1,461,830 1,702,290 1,591,771 418,448 $18,684,123 $12,067,535 $10,681,879 Jan 17 1,491,887 1,745,023 1,873,622 1,855,506 418,457 $12,363,090 $9,284,807 $10,229,253 Feb 17 1,398,791 1,649,920 1,721,646 1,734,010 447,044 $11,517,410 $7,943,048 $8,360,658 Mar 17 1,925,710 2,008,918 1,965,516 2,193,546 265,434 $9,056,101 $5,158,661 $5,118,041 Apr 17 2,364,984 2,543,514 2,174,480 2,532,826 May 17 Jun 17 Jul 17 Aug 17 Sep 17 Total 11,208,556 12,191,230 13,073,966 12,724,939 2,312,521 $82,547,838 $56,873,011 $52,881,365 Actual generation as a percentage of average: 97.3% Cost per MWh: $22.87

Western Area Power Administration (WAPA) generated a total of 12,725 gigawatt-hours (GWh) during October through April of fiscal year 2017, or 97.3 percent of the average. Actual purchase power data is currently available from October through March for all of WAPA’s Regions, and during this period total purchase power was 2,313 GWh and total purchase power expenses were $52,881,365, which equates to $22.87 per MWh.

Colorado River Storage Project

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.30 0.20 514.42 381.00 15.01 12.68 248,012 340,536 382,430 384,045 64,165 $6,704,081 $1,491,591 $1,683,280 Nov 16 4.80 2.60 474.23 383.00 14.91 12.31 230,952 315,541 388,155 334,811 127,238 $7,549,826 $2,850,078 $3,213,841 Dec 16 8.10 8.50 362.96 300.00 14.86 11.80 270,310 445,186 437,962 460,333 48,822 $7,692,571 $1,292,373 $1,282,528 Jan 17 11.50 16.00 361.45 359.00 14.98 11.36 355,138 431,244 457,394 455,508 57,227 $4,412,679 $1,231,482 $1,678,096 Feb 17 15.10 21.00 392.01 555.00 15.99 11.22 265,647 387,432 390,580 393,646 61,657 $5,024,221 $1,531,108 $1,555,701 Mar 17 18.90 22.00 666.27 1,110.00 16.77 11.36 272,465 405,609 390,170 458,176 29,840 $5,517,603 $1,111,921 $644,587 Apr 17 19.40 21.00 1,057.14 1,607.00 16.74 12.15 250,695 404,074 397,861 427,891 10,935 $3,468,325 $93,697 $210,181 May 17 Jun 17 Jul 17 Aug 17 Sep 17 Total 1,893,220 2,729,621 2,844,551 2,914,410 399,884 $40,369,305 $9,602,250 $10,268,214 Actual generation as a percentage of average: 102.5% Cost per MWh: $25.68

Lake/Reservoir Levels Lake Powell’s elevation was 3,604 feet at the end of April, about 96 feet below the maximum reservoir level and about 114 feet above the minimum generation level. The storage volume for Lake Powell was 12.15 million acre-feet at the end of April, which is about 50 percent of capacity.

Weather and Other Conditions The April-July inflow forecasts continue to run slightly above average with a mid-May inflow forecast of 116% of average. Current forecasts estimate Lake Powell will increase about 37 feet in elevation by the end of August.

Desert Southwest Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.30 0.20 60.29 79.00 20.40 11.75 282,630 282,630 378,811 290,888 5,020 $165,459 $165,459 $165,459 Nov 16 4.80 2.60 54.10 78.00 20.31 11.90 345,830 373,020 363,391 374,705 1,919 $90,031 $64,805 $65,277 Dec 16 8.10 8.50 73.53 63.00 20.44 12.31 254,600 268,015 372,094 277,597 13,258 $388,103 $289,603 $510,168 Jan 17 11.50 16.00 93.88 126.00 20.59 12.80 284,450 253,225 395,966 255,068 21,520 $535,169 $535,169 $800,974 Feb 17 15.10 21.00 110.31 148.00 20.62 13.11 328,350 292,965 390,077 268,179 2,595 $0 $0 $83,974 Mar 17 18.90 22.00 102.80 99.00 20.40 13.00 558,800 504,200 531,483 496,001 12,330 $72,840 $391,582 $330,814 Apr 17 19.40 21.00 84.98 94.00 20.25 12.70 524,735 524,735 571,605 537,707 4,094 $93,243 $93,243 $112,012 May 17 Jun 17 Jul 17 Aug 17 Sep 17 Total 2,579,395 2,498,790 3,003,427 2,500,145 60,736 $1,344,845 $1,539,861 $2,068,678 Actual generation as a percentage of average: 83.2% Cost per MWh: $34.06

Lake/Reservoir Levels Lake Mead’s elevation was 1,085 feet at the end of April, about 135 feet below full storage level and about 135 feet above the new minimum generation level of 950 feet. Lake Mead started the water year with a minimum elevation of 1,076 feet in October and reached a peak elevation of 1,090 feet in February.

Rocky Mountain Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 138.60 177.30 3.85 4.66 93,769 98,500 82,866 90,186 56,146 $1,918,912 $1,768,512 $1,371,457 Nov 16 120.30 145.10 3.85 4.72 57,639 59,762 78,718 56,073 88,908 $3,104,240 $3,033,840 $2,226,606 Dec 16 268.10 160.50 98.80 106.40 3.82 4.69 91,252 93,448 101,061 102,574 73,018 $2,601,536 $2,534,336 $2,020,033 Jan 17 417.90 452.40 96.60 114.70 3.79 4.67 108,118 110,236 111,274 127,252 33,352 $2,062,592 $1,995,392 $1,205,222 Feb 17 849.60 1,170.80 96.30 173.50 3.79 4.79 97,795 99,700 99,585 129,713 4,671 $1,254,624 $1,193,824 $143,568 Mar 17 1,105.20 1,524.90 159.00 293.50 4.13 4.70 124,712 136,697 118,178 191,665 0 $785,728 $401,728 $0 Apr 17 1,342.80 1,552.90 250.20 462.40 3.85 4.50 135,854 164,886 138,114 246,662 4,244 $1,295,328 $367,328 $55,309 May 17 Jun 17 Jul 17 Aug 17 Sep 17 Total 709,138 763,228 729,797 944,125 260,339 $13,022,960 $11,294,960 $7,022,195 Actual generation as a percentage of average: 129.4% Cost per MWh: $26.97

Lake/Reservoir Content The overall reservoir content at the end of April was 117 percent of average.

Weather and Other Conditions The entire Loveland Area Projects (LAP) area is now considered to be drought free due to recent spring storms. The snowpack is now above average in the Upper North Platte River Basin, well above average in the Upper Colorado River headwaters, and far above average in the Bighorn River Basin. The May forecasts of most probable reservoir inflows from spring runoff is above average for the Colorado-Big Thompson Project (CBT) and the North Platte River Basin, and well above average for the Bighorn River Basin. The latest National Weather Service forecast indicates June through August temperatures are just as likely to be above as below normal, and the precipitation is more likely to be above normal in the LAP area.

Note: The Rocky Mountain Region’s (RMR) most recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 336.00 561.00 5.26 4.66 121,000 146,000 163,000 100,955 56,052 $1,179,286 $1,179,286 $1,536,064 Nov 16 4.76 3.00 399.00 706.00 5.21 4.99 104,000 34,000 104,000 42,525 57,080 $1,139,734 $1,139,734 $1,582,259 Dec 16 9.09 6.00 1,046.00 1,621.00 5.72 5.63 79,000 19,000 143,000 115,177 54,748 $1,179,286 $1,179,286 $1,280,611 Jan 17 27.78 30.00 1,167.00 3,436.00 6.13 6.43 78,000 293,000 163,000 385,479 32,534 $499,500 $499,500 $643,343 Feb 17 27.78 45.00 1,339.00 5,725.00 6.71 7.68 139,000 300,000 195,000 439,436 19,673 $479,520 $479,520 $579,856 Mar 17 28.22 46.00 1,553.00 2,574.00 7.46 8.61 290,000 330,000 207,000 399,223 26,567 $539,460 $539,460 $642,682 Apr 17 25.77 42.00 1,380.00 2,758.00 7.88 9.29 431,000 426,000 288,000 426,215 20,095 $499,500 $499,500 $555,974 May 17 Jun 17 Jul 17 Aug 17 Sep 17 Total 1,242,000 1,548,000 1,263,000 1,909,011 266,749 $5,516,286 $5,516,286 $6,820,789 Actual generation as a percentage of average: 151.1% Cost per MWh: $25.57

Lake/Reservoir Content As of April 30, accumulated inflow for the water year was 215 percent of the 15-year average for Trinity, 207 percent for Shasta, 351 percent for Folsom, and 311 percent for New Melones. Reservoir storage as of the same date was 123 percent of the 15-year average for Trinity, 112 percent for Shasta, 95 percent for Folsom, and 123 percent for New Melones.

Weather and Other Conditions As of April 30, cumulative precipitation of the Northern Sierra Eight Station Index was at 197 percent of average for the date. This water year will be officially designated as “wet.”

Note: The Sierra Nevada Region’s (SNR) average generation is based upon long-term modeling done for its "Green Book." SNR does not project purchase power expenses for dry conditions, and its most probable expenses are based upon term purchases of 35 to 65 percent of projected power needs, with the difference being left to day-ahead markets after project pumping and generation have been scheduled.

Upper Great Plains Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.20 0.40 8,092.00 5,601.83 55.94 58.67 569,606 558,761 868,863 561,879 146,071 $4,699,887 $4,916,797 $3,414,114 Nov 16 3.80 1.40 7,411.00 5,690.87 54.83 58.32 644,937 573,277 826,179 581,212 160,538 $4,375,658 $5,808,858 $3,233,177 Dec 16 7.10 5.60 6,468.00 5,454.05 54.23 57.60 633,647 636,181 648,173 636,090 228,602 $6,822,627 $6,771,937 $5,588,539 Jan 17 10.30 7.80 6,659.00 5,727.89 54.03 57.50 666,182 657,318 745,987 632,199 273,824 $4,853,151 $5,023,264 $5,901,618 Feb 17 12.90 12.70 6,300.00 5,706.99 54.34 58.54 568,000 569,823 646,404 503,036 358,448 $4,759,045 $4,738,596 $5,997,559 Mar 17 15.80 14.80 8,219.00 7,544.34 56.08 59.94 679,733 632,412 718,685 648,481 196,697 $2,140,470 $2,713,970 $3,499,958 Apr 17 15.10 16.00 8,052.00 9,087.27 56.95 60.50 1,022,700 1,023,820 778,900 894,351 * $1,032,790 $1,044,144 * May 17 Jun 17 Jul 17 Aug 17 Sep 17 Total 4,784,804 4,651,591 5,233,191 4,457,248 1,364,180 $28,683,628 $31,017,566 $27,634,965 Actual generation as a percentage of average: 85.2% Cost per MWh: $20.26

Lake/Reservoir Content As of May 22, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 87.3 percent and 72.7 percent full, respectively.

Weather and Other Conditions Most of the plains snowpack melted in March, which produced a below-average runoff for April of 93 percent. However, snowpack accumulations have since increased significantly to 107 percent of average above Fort Peck and 155 percent of average on the Garrison to Fort Peck reach, and late spring storms continue to add to the snowpack totals.

Note: The Upper Great Plains Region reports its 50 percent share of generation from Yellowtail Dam, while RMR reports the snowpack, inflow, content, and remaining share of generation. Asterisks indicate that actual data is not available for the month.

6 WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT June 2017

Agency-wide Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1,315,017 1,426,426 1,875,969 1,427,953 327,454 $14,667,625 $9,521,646 $8,170,374 Nov 16 1,383,358 1,355,599 1,760,444 1,389,326 435,683 $16,259,488 $12,897,315 $10,321,160 Dec 16 1,328,808 1,461,830 1,702,290 1,591,771 418,448 $18,684,123 $12,067,535 $10,681,879 Jan 17 1,491,887 1,745,023 1,873,622 1,855,506 418,457 $12,363,090 $9,284,807 $10,229,253 Feb 17 1,398,791 1,649,920 1,721,646 1,734,010 447,044 $11,517,410 $7,943,048 $8,360,658 Mar 17 1,925,710 2,008,918 1,965,516 2,193,546 265,434 $9,056,101 $5,158,661 $5,118,041 Apr 17 2,364,984 2,543,514 2,174,480 2,532,826 65,008 $6,389,186 $2,097,912 $1,208,074 May 17 2,665,575 2,932,309 2,508,027 2,890,931 Jun 17 Jul 17 Aug 17 Sep 17 Total 13,874,131 15,123,539 15,581,992 15,615,870 2,377,529 $88,937,024 $58,970,923 $54,089,439 Actual generation as a percentage of average: 100.2% Cost per MWh: $22.75

Western Area Power Administration (WAPA) generated a total of 15,616 gigawatt-hours (GWh) during October through May of fiscal year 2017, or 100.2 percent of the average. Actual purchase power data is currently available from October through April for all of WAPA’s Regions, and during this period total purchase power was 2,378 GWh and total purchase power expenses were $54,089,439, which equates to $22.75 per MWh.

Colorado River Storage Project

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.30 0.20 514.42 381.00 15.01 12.68 248,012 340,536 382,430 384,045 64,165 $6,704,081 $1,491,591 $1,683,280 Nov 16 4.80 2.60 474.23 383.00 14.91 12.31 230,952 315,541 388,155 334,811 127,238 $7,549,826 $2,850,078 $3,213,841 Dec 16 8.10 8.50 362.96 300.00 14.86 11.80 270,310 445,186 437,962 460,333 48,822 $7,692,571 $1,292,373 $1,282,528 Jan 17 11.50 16.00 361.45 359.00 14.98 11.36 355,138 431,244 457,394 455,508 57,227 $4,412,679 $1,231,482 $1,678,096 Feb 17 15.10 21.00 392.01 555.00 15.99 11.22 265,647 387,432 390,580 393,646 61,657 $5,024,221 $1,531,108 $1,555,701 Mar 17 18.90 22.00 666.27 1,110.00 16.77 11.36 272,465 405,609 390,170 458,176 29,840 $5,517,603 $1,111,921 $644,587 Apr 17 19.40 21.00 1,057.14 1,607.00 16.74 12.15 250,695 404,074 397,861 427,891 10,935 $3,468,325 $93,697 $210,181 May 17 7.90 11.00 2,337.68 2,377.00 16.30 13.67 320,070 572,228 501,886 553,204 86,530 $2,044,585 $1,990,190 $1,455,945 Jun 17 Jul 17 Aug 17 Sep 17 Total 2,213,290 3,301,850 3,346,438 3,467,614 486,414 $42,413,890 $11,592,440 $11,724,159 Actual generation as a percentage of average: 103.6% Cost per MWh: $24.10

Lake/Reservoir Levels Lake Powell’s elevation was 3,619 feet at the end of May, about 81 feet below the maximum reservoir level and about 129 feet above the minimum generation level. The storage volume for Lake Powell was 13.67 million acre-feet at the end of May, which is about 56 percent of capacity.

Weather and Other Conditions The April-July inflow forecasts continue to run slightly above average with a June inflow forecast of 116% of average. Current forecasts estimate Lake Powell elevation will be 3,632 feet at the end of water year 2017, about 22 feet higher than the end of water year 2016.

Desert Southwest Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.30 0.20 60.29 79.00 20.40 11.75 282,630 282,630 378,811 290,888 5,020 $165,459 $165,459 $165,459 Nov 16 4.80 2.60 54.10 78.00 20.31 11.90 345,830 373,020 363,391 374,705 1,919 $90,031 $64,805 $65,277 Dec 16 8.10 8.50 73.53 63.00 20.44 12.31 254,600 268,015 372,094 277,597 13,258 $388,103 $289,603 $510,168 Jan 17 11.50 16.00 93.88 126.00 20.59 12.80 284,450 253,225 395,966 255,068 21,520 $535,169 $535,169 $800,974 Feb 17 15.10 21.00 110.31 148.00 20.62 13.11 328,350 292,965 390,077 268,179 2,595 $0 $0 $83,974 Mar 17 18.90 22.00 102.80 99.00 20.40 13.00 558,800 504,200 531,483 496,001 12,330 $72,840 $391,582 $330,814 Apr 17 19.40 21.00 84.98 94.00 20.25 12.70 524,735 524,735 571,605 537,707 4,094 $93,243 $93,243 $112,012 May 17 7.90 11.00 59.42 40.00 20.36 12.45 487,280 487,280 571,204 491,336 22,788 $595,658 $595,658 $777,754 Jun 17 Jul 17 Aug 17 Sep 17 Total 3,066,675 2,986,070 3,574,631 2,991,482 83,524 $1,940,503 $2,135,519 $2,846,432 Actual generation as a percentage of average: 83.7% Cost per MWh: $34.08

Lake/Reservoir Levels Lake Mead’s elevation was 1,082 feet at the end of May, about 138 feet below the full storage level and about 132 feet above the new minimum generation level of 950 feet. Lake Mead started the water year with a minimum elevation of 1,076 feet in October and reached a peak elevation of 1,090 feet in February.

Rocky Mountain Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 138.60 177.30 3.85 4.66 93,769 98,500 82,866 90,186 56,146 $1,918,912 $1,768,512 $1,371,457 Nov 16 120.30 145.10 3.85 4.72 57,639 59,762 78,718 56,073 88,908 $3,104,240 $3,033,840 $2,226,606 Dec 16 268.10 160.50 98.80 106.40 3.82 4.69 91,252 93,448 101,061 102,574 73,018 $2,601,536 $2,534,336 $2,020,033 Jan 17 417.90 452.40 96.60 114.70 3.79 4.67 108,118 110,236 111,274 127,252 33,352 $2,062,592 $1,995,392 $1,205,222 Feb 17 849.60 1,170.80 96.30 173.50 3.79 4.79 97,795 99,700 99,585 129,713 4,671 $1,254,624 $1,193,824 $143,568 Mar 17 1,105.20 1,524.90 159.00 293.50 4.13 4.70 124,712 136,697 118,178 191,665 0 $785,728 $401,728 $0 Apr 17 1,342.80 1,552.90 250.20 462.40 3.85 4.50 135,854 164,886 138,114 246,662 4,244 $1,295,328 $367,328 $55,309 May 17 1,231.50 1,441.80 696.50 1,120.10 4.19 4.41 217,579 252,286 197,941 245,229 8,104 $0 $0 $116,918 Jun 17 Jul 17 Aug 17 Sep 17 Total 926,717 1,015,514 927,738 1,189,354 268,443 $13,022,960 $11,294,960 $7,139,113 Actual generation as a percentage of average: 128.2% Cost per MWh: $26.59

Lake/Reservoir Content The overall reservoir content at the end of May was 105 percent of average.

Weather and Other Conditions The entire Loveland Area Projects (LAP) area is now considered to be drought free. The snowpack has almost completely melted at all but the highest elevations and the peak spring runoff has passed. The June forecasts of most probable reservoir inflows from the spring runoff remain above average for the Colorado-Big Thompson Project (CBT) and the North Platte River Basin and well above average for the Bighorn River Basin. The storage in the CBT and North Platte reservoirs was above average at the end of May but the storage in the Bighorn Basin reservoirs was below average as Reclamation made record releases in anticipation of very large spring runoff volumes. The latest National Weather Service forecast indicates July through September temperatures are more likely to be above normal and the precipitation is just as likely to be above as below normal in the LAP area. Surplus LAP generation is expected to continue into early July.

Note: The Rocky Mountain Region’s (RMR) most recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 336.00 561.00 5.26 4.66 121,000 146,000 163,000 100,955 56,052 $1,179,286 $1,179,286 $1,536,064 Nov 16 4.76 3.00 399.00 706.00 5.21 4.99 104,000 34,000 104,000 42,525 57,080 $1,139,734 $1,139,734 $1,582,259 Dec 16 9.09 6.00 1,046.00 1,621.00 5.72 5.63 79,000 19,000 143,000 115,177 54,748 $1,179,286 $1,179,286 $1,280,611 Jan 17 27.78 30.00 1,167.00 3,436.00 6.13 6.43 78,000 293,000 163,000 385,479 32,534 $499,500 $499,500 $643,343 Feb 17 27.78 45.00 1,339.00 5,725.00 6.71 7.68 139,000 300,000 195,000 439,436 19,673 $479,520 $479,520 $579,856 Mar 17 28.22 46.00 1,553.00 2,574.00 7.46 8.61 290,000 330,000 207,000 399,223 26,567 $539,460 $539,460 $642,682 Apr 17 25.77 42.00 1,380.00 2,758.00 7.88 9.29 431,000 426,000 288,000 426,215 20,089 $499,500 $499,500 $555,974 May 17 27.87 17.00 1,303.00 2,259.00 7.91 9.66 526,000 516,000 442,000 617,375 11,820 $519,480 $519,480 $582,074 Jun 17 Jul 17 Aug 17 Sep 17 Total 1,768,000 2,064,000 1,705,000 2,526,386 278,565 $6,035,766 $6,035,766 $7,402,863 Actual generation as a percentage of average: 148.2% Cost per MWh: $26.58

Lake/Reservoir Content As of May 31, accumulated inflow for the water year was 185 percent of the 15-year average for Trinity, 195 percent for Shasta, 308 percent for Folsom, and 292 percent for New Melones. Reservoir storage as of the same date was 123 percent of the 15-year average for Trinity, 116 percent for Shasta, 116 percent for Folsom, and 142 percent for New Melones.

Weather and Other Conditions As of May 31, cumulative precipitation of the Northern Sierra Eight Station Index was at 189 percent of average for the date; however, May ended at only 17 percent of its monthly average. The May 1 forecast for the 50 percent exceedence case is the basis for the official year type declaration, which is "wet" for this water year.

Upper Great Plains Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.20 0.40 8,092.00 5,601.83 55.94 58.67 569,606 558,761 868,863 561,879 146,071 $4,699,887 $4,916,797 $3,414,114 Nov 16 3.80 1.40 7,411.00 5,690.87 54.83 58.32 644,937 573,277 826,179 581,212 160,538 $4,375,658 $5,808,858 $3,233,177 Dec 16 7.10 5.60 6,468.00 5,454.05 54.23 57.60 633,647 636,181 648,173 636,090 228,602 $6,822,627 $6,771,937 $5,588,539 Jan 17 10.30 7.80 6,659.00 5,727.89 54.03 57.50 666,182 657,318 745,987 632,199 273,824 $4,853,151 $5,023,264 $5,901,618 Feb 17 12.90 12.70 6,300.00 5,706.99 54.34 58.54 568,000 569,823 646,404 503,036 358,448 $4,759,045 $4,738,596 $5,997,559 Mar 17 15.80 14.80 8,219.00 7,544.34 56.08 59.94 679,733 632,412 718,685 648,481 196,697 $2,140,470 $2,713,970 $3,499,958 Apr 17 15.10 16.00 8,052.00 9,087.27 56.95 60.50 1,022,700 1,023,820 778,900 894,351 25,646 $1,032,790 $1,044,144 $274,598 May 17 6.60 6.50 9,692.00 10,815.22 58.22 61.97 1,114,646 1,104,515 794,995 983,787 * $308,233 $329,579 * Jun 17 Jul 17 Aug 17 Sep 17 Total 5,899,450 5,756,106 6,028,186 5,441,035 1,389,826 $28,991,861 $31,347,145 $27,909,563 Actual generation as a percentage of average: 90.3% Cost per MWh: $20.08

Lake/Reservoir Content As of June 19, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 99.2 percent and 87.6 percent full, respectively.

Weather and Other Conditions Good spring rains throughout the Missouri River Basin created an above-normal runoff of 129 percent for May. Snowpack accumulations peaked on May 2 at 99 percent of average above Fort Peck and 148 percent of average on the Garrison to Fort Peck reach. Bird peaking schedules continued in May at Garrison. Fort Randall is experiencing extended maintenance outages that have caused the Corps of Engineers to spill to meet water releases, and two units will remain out of service until the end of June.

6 WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT July 2017

Agency-wide Purchase Power Generation (Megawatt-Hours [MWh]) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1,315,017 1,426,426 1,875,969 1,427,953 327,454 $14,667,625 $9,521,646 $8,170,374 Nov 16 1,383,358 1,355,599 1,760,444 1,389,326 435,683 $16,259,488 $12,897,315 $10,321,160 Dec 16 1,328,808 1,461,830 1,702,290 1,591,771 418,448 $18,684,123 $12,067,535 $10,681,879 Jan 17 1,491,887 1,745,023 1,873,622 1,855,506 418,457 $12,363,090 $9,284,807 $10,229,253 Feb 17 1,398,791 1,649,920 1,721,646 1,734,010 447,044 $11,517,410 $7,943,048 $8,360,658 Mar 17 1,925,710 2,008,918 1,965,516 2,193,546 265,434 $9,056,101 $5,158,661 $5,118,041 Apr 17 2,364,984 2,543,514 2,174,480 2,532,826 65,008 $6,389,186 $2,097,912 $1,208,074 May 17 2,665,575 2,932,309 2,508,027 2,891,132 140,001 $3,467,957 $3,434,907 $2,990,589 Jun 17 2,768,173 3,078,396 2,621,548 2,966,706 Jul 17 Aug 17 Sep 17 Total 16,642,304 18,201,935 18,203,540 18,582,777 2,517,531 $92,404,981 $62,405,830 $57,080,028 Actual generation as a percentage of average: 102.1% Cost per MWh: $22.67

Western Area Power Administration (WAPA) generated a total of 18,583 gigawatt-hours (GWh) during October through June of fiscal year 2017, or 102.1 percent of the average. Actual purchase power data is currently available from October through May for all of WAPA’s Regions, and during this period total purchase power was 2,518 GWh and total purchase power expenses were $57,080,028, which equates to $22.67 per MWh.

Colorado River Storage Project

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.30 0.20 514.42 381.00 15.01 12.68 248,012 340,536 382,430 384,045 64,165 $6,704,081 $1,491,591 $1,683,280 Nov 16 4.80 2.60 474.23 383.00 14.91 12.31 230,952 315,541 388,155 334,811 127,238 $7,549,826 $2,850,078 $3,213,841 Dec 16 8.10 8.50 362.96 300.00 14.86 11.80 270,310 445,186 437,962 460,333 48,822 $7,692,571 $1,292,373 $1,282,528 Jan 17 11.50 16.00 361.45 359.00 14.98 11.36 355,138 431,244 457,394 455,508 57,227 $4,412,679 $1,231,482 $1,678,096 Feb 17 15.10 21.00 392.01 555.00 15.99 11.22 265,647 387,432 390,580 393,646 61,657 $5,024,221 $1,531,108 $1,555,701 Mar 17 18.90 22.00 666.27 1,110.00 16.77 11.36 272,465 405,609 390,170 458,176 29,840 $5,517,603 $1,111,921 $644,587 Apr 17 19.40 21.00 1,057.14 1,607.00 16.74 12.15 250,695 404,074 397,861 427,891 10,935 $3,468,325 $93,697 $210,181 May 17 7.90 11.00 2,337.68 2,377.00 16.30 13.67 320,070 572,228 501,886 553,204 86,530 $2,044,585 $1,990,190 $1,455,945 Jun 17 0.00 1.00 2,668.50 3,115.00 16.00 15.41 337,289 607,167 585,467 592,541 2,885 $2,301,440 $22,746 $44,051 Jul 17 Aug 17 Sep 17 Total 2,550,579 3,909,016 3,931,905 4,060,155 489,299 $44,715,330 $11,615,186 $11,768,210 Actual generation as a percentage of average: 103.3% Cost per MWh: $24.05

Lake/Reservoir Levels Lake Powell’s elevation was 3,635 feet at the end of June, about 65 feet below the maximum reservoir level and about 145 feet above the minimum generation level. The storage volume for Lake Powell was 15.41 million acre-feet at the end of June, which is about 63 percent of capacity.

Weather and Other Conditions Current forecasts estimate Lake Powell elevation will be 3,631 feet at the end of water year 2017, about 20 feet higher than at the end of water year 2016.

Desert Southwest Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.30 0.20 60.29 79.00 20.40 11.75 282,630 282,630 378,811 290,888 5,020 $165,459 $165,459 $165,459 Nov 16 4.80 2.60 54.10 78.00 20.31 11.90 345,830 373,020 363,391 374,705 1,919 $90,031 $64,805 $65,277 Dec 16 8.10 8.50 73.53 63.00 20.44 12.31 254,600 268,015 372,094 277,597 13,258 $388,103 $289,603 $510,168 Jan 17 11.50 16.00 93.88 126.00 20.59 12.80 284,450 253,225 395,966 255,068 21,520 $535,169 $535,169 $800,974 Feb 17 15.10 21.00 110.31 148.00 20.62 13.11 328,350 292,965 390,077 268,179 2,595 $0 $0 $83,974 Mar 17 18.90 22.00 102.80 99.00 20.40 13.00 558,800 504,200 531,483 496,001 12,330 $72,840 $391,582 $330,814 Apr 17 19.40 21.00 84.98 94.00 20.25 12.70 524,735 524,735 571,605 537,707 4,094 $93,243 $93,243 $112,012 May 17 7.90 11.00 59.42 40.00 20.36 12.45 487,280 487,280 571,204 491,336 22,788 $595,658 $595,658 $777,754 Jun 17 0.00 1.00 26.38 18.00 20.56 12.26 467,615 467,615 537,300 466,470 8,885 $582,202 $582,202 $687,310 Jul 17 Aug 17 Sep 17 Total 3,534,290 3,453,685 4,111,931 3,457,952 92,409 $2,522,705 $2,717,721 $3,533,742 Actual generation as a percentage of average: 84.1% Cost per MWh: $38.24

Lake/Reservoir Levels Lake Mead’s elevation was 1,080 feet at the end of June, about 140 feet below the full storage level and about 130 feet above the new minimum generation level of 950 feet. Lake Mead started the water year with a minimum elevation of 1,076 feet in October and reached a peak elevation of 1,090 feet in February.

Rocky Mountain Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 138.60 177.30 3.85 4.66 93,769 98,500 82,866 90,186 56,146 $1,918,912 $1,768,512 $1,371,457 Nov 16 120.30 145.10 3.85 4.72 57,639 59,762 78,718 56,073 88,908 $3,104,240 $3,033,840 $2,226,606 Dec 16 268.10 160.50 98.80 106.40 3.82 4.69 91,252 93,448 101,061 102,574 73,018 $2,601,536 $2,534,336 $2,020,033 Jan 17 417.90 452.40 96.60 114.70 3.79 4.67 108,118 110,236 111,274 127,252 33,352 $2,062,592 $1,995,392 $1,205,222 Feb 17 849.60 1,170.80 96.30 173.50 3.79 4.79 97,795 99,700 99,585 129,713 4,671 $1,254,624 $1,193,824 $143,568 Mar 17 1,105.20 1,524.90 159.00 293.50 4.13 4.70 124,712 136,697 118,178 191,665 0 $785,728 $401,728 $0 Apr 17 1,342.80 1,552.90 250.20 462.40 3.85 4.50 135,854 164,886 138,114 246,662 4,244 $1,295,328 $367,328 $55,309 May 17 1,231.50 1,441.80 696.50 1,120.10 4.19 4.41 217,579 252,286 197,941 245,430 8,104 $0 $0 $116,918 Jun 17 304.70 579.90 1,124.80 2,054.20 4.76 5.78 231,289 311,890 244,139 300,898 2,747 $0 $0 $68,880 Jul 17 Aug 17 Sep 17 Total 1,158,006 1,327,404 1,171,877 1,490,453 271,190 $13,022,960 $11,294,960 $7,207,993 Actual generation as a percentage of average: 127.2% Cost per MWh: $26.58

Lake/Reservoir Content The overall reservoir content at the end of June was 121 percent of average.

Weather and Other Conditions The Loveland Area Projects (LAP) area remains drought free but the trend is for drier conditions in some areas. The latest National Weather Service forecast indicates August through October temperatures are more likely to be above normal, and the precipitation is just as likely to be above as below normal in Wyoming and eastern Colorado while more likely to be above normal west of the Continental Divide in Colorado. LAP generation is expected to be less than the marketed amount through next March. Releases to evacuate space in reservoirs for the anticipated runoff required bypasses at some power plants, and a portion of the Yellowtail plant bypass was initiated at the request of WAPA to provide reserve capacity and regulating capability as other plants are loaded to capacity. Furthermore, Colorado-Big Thompson Project generation will be restricted during a Charles Hansen Feeder Canal siphon repair scheduled from August through mid-November.

Note: The Rocky Mountain Region’s (RMR) most recent reported purchase power data are provisional values and may change.

Sierra Nevada Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 336.00 561.00 5.26 4.66 121,000 146,000 163,000 100,955 56,052 $1,179,286 $1,179,286 $1,536,064 Nov 16 4.76 3.00 399.00 706.00 5.21 4.99 104,000 34,000 104,000 42,525 57,080 $1,139,734 $1,139,734 $1,582,259 Dec 16 9.09 6.00 1,046.00 1,621.00 5.72 5.63 79,000 19,000 143,000 115,177 54,748 $1,179,286 $1,179,286 $1,280,611 Jan 17 27.78 30.00 1,167.00 3,436.00 6.13 6.43 78,000 293,000 163,000 385,479 32,534 $499,500 $499,500 $643,343 Feb 17 27.78 45.00 1,339.00 5,725.00 6.71 7.68 139,000 300,000 195,000 439,436 19,673 $479,520 $479,520 $579,856 Mar 17 28.22 46.00 1,553.00 2,574.00 7.46 8.61 290,000 330,000 207,000 399,223 26,567 $539,460 $539,460 $642,682 Apr 17 25.77 42.00 1,380.00 2,758.00 7.88 9.29 431,000 426,000 288,000 426,215 20,089 $499,500 $499,500 $555,974 May 17 27.87 17.00 1,303.00 2,259.00 7.91 9.66 526,000 516,000 442,000 617,375 11,820 $519,480 $519,480 $582,074 Jun 17 0.00 2.00 804.00 1,320.00 7.49 9.51 537,000 522,000 440,000 469,577 31,382 $519,480 $519,480 $845,693 Jul 17 Aug 17 Sep 17 Total 2,305,000 2,586,000 2,145,000 2,995,963 309,947 $6,555,246 $6,555,246 $8,248,555 Actual generation as a percentage of average: 139.7% Cost per MWh: $26.61

Lake/Reservoir Content As of June 30, accumulated inflow for the water year was 175 percent of the 15-year average for Trinity, 190 percent for Shasta, 298 percent for Folsom and 288 percent for New Melones. Reservoir storage as of the same date was 120 percent of the 15-year average for Trinity, 122 percent for Shasta, 127 percent for Folsom and 149 percent for New Melones.

Weather and Other Conditions As of June 30, cumulative precipitation of the Northern Sierra Eight Station Index was at 187 percent of average for the date. May ended at only 17 percent of its monthly precipitation average; however, June ended at 87 percent of its monthly average. The May 1 forecast for the 50 percent exceedence case is the basis for the official year type declaration, which is "wet" for this water year.

Upper Great Plains Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.20 0.40 8,092.00 5,601.83 55.94 58.67 569,606 558,761 868,863 561,879 146,071 $4,699,887 $4,916,797 $3,414,114 Nov 16 3.80 1.40 7,411.00 5,690.87 54.83 58.32 644,937 573,277 826,179 581,212 160,538 $4,375,658 $5,808,858 $3,233,177 Dec 16 7.10 5.60 6,468.00 5,454.05 54.23 57.60 633,647 636,181 648,173 636,090 228,602 $6,822,627 $6,771,937 $5,588,539 Jan 17 10.30 7.80 6,659.00 5,727.89 54.03 57.50 666,182 657,318 745,987 632,199 273,824 $4,853,151 $5,023,264 $5,901,618 Feb 17 12.90 12.70 6,300.00 5,706.99 54.34 58.54 568,000 569,823 646,404 503,036 358,448 $4,759,045 $4,738,596 $5,997,559 Mar 17 15.80 14.80 8,219.00 7,544.34 56.08 59.94 679,733 632,412 718,685 648,481 196,697 $2,140,470 $2,713,970 $3,499,958 Apr 17 15.10 16.00 8,052.00 9,087.27 56.95 60.50 1,022,700 1,023,820 778,900 894,351 25,646 $1,032,790 $1,044,144 $274,598 May 17 6.60 6.50 9,692.00 10,815.22 58.22 61.97 1,114,646 1,104,515 794,995 983,787 10,759 $308,233 $329,579 $57,898 Jun 17 0.60 0.20 11,809.00 12,545.36 60.45 63.67 1,194,980 1,169,724 814,641 1,137,220 * $54,138 $65,770 * Jul 17 Aug 17 Sep 17 Total 7,094,430 6,925,830 6,842,827 6,578,255 1,400,585 $29,046,000 $31,412,916 $27,967,461 Actual generation as a percentage of average: 96.1% Cost per MWh: $19.97

Lake/Reservoir Content As of July 12, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 98.9 percent and 100 percent full, respectively.

Weather and Other Conditions The June runoff in the upper basin was 106 percent of average, with snowpack being the primary source of runoff in the Fort Peck and Garrison reaches. However, the lower basin had precipitation of less than 50 percent of average which resulted in below-average runoff for Oahe, Fort Randall, and Gavins Point. Drought conditions have been worsening this past month, with extreme drought in northeastern Montana, western North Dakota, and north central South Dakota. Two units at Fort Randall are out of service through the summer due to cable tray replacements.

6 WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT August 2017

Due to the lack of current hydro data and related information for a Western Area Power Administration (WAPA) Region, this August 2017 hydro conditions report is being issued in preliminary form without an agency-wide data table or narrative summary. A final report with the table and summary will be distributed at a later date when all current Regional data is available.

Colorado River Storage Project

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.30 0.20 514.42 381.00 15.01 12.68 248,012 340,536 382,430 384,045 64,165 $6,704,081 $1,491,591 $1,683,280 Nov 16 4.80 2.60 474.23 383.00 14.91 12.31 230,952 315,541 388,155 334,811 127,238 $7,549,826 $2,850,078 $3,213,841 Dec 16 8.10 8.50 362.96 300.00 14.86 11.80 270,310 445,186 437,962 460,333 48,822 $7,692,571 $1,292,373 $1,282,528 Jan 17 11.50 16.00 361.45 359.00 14.98 11.36 355,138 431,244 457,394 455,508 57,227 $4,412,679 $1,231,482 $1,678,096 Feb 17 15.10 21.00 392.01 555.00 15.99 11.22 265,647 387,432 390,580 393,646 61,657 $5,024,221 $1,531,108 $1,555,701 Mar 17 18.90 22.00 666.27 1,110.00 16.77 11.36 272,465 405,609 390,170 458,176 29,840 $5,517,603 $1,111,921 $644,587 Apr 17 19.40 21.00 1,057.14 1,607.00 16.74 12.15 250,695 404,074 397,861 427,891 10,935 $3,468,325 $93,697 $210,181 May 17 7.90 11.00 2,337.68 2,377.00 16.30 13.67 320,070 572,228 501,886 553,204 86,530 $2,044,585 $1,990,190 $1,455,945 Jun 17 0.00 1.00 2,668.50 3,115.00 16.00 15.41 337,289 607,167 585,467 592,541 2,885 $2,301,440 $22,746 $44,051 Jul 17 0.00 1.10 1,093.88 1,073.00 15.88 15.39 436,357 505,605 612,093 556,270 4,635 $708,807 $70,408 $97,798 Aug 17 Sep 17 Total 2,986,936 4,414,621 4,543,998 4,616,425 493,934 $45,424,137 $11,685,594 $11,866,008 Actual generation as a percentage of average: 101.6% Cost per MWh: $24.02

Lake/Reservoir Levels Lake Powell’s elevation was 3,635 feet at the end of July, about 65 feet below the maximum reservoir level and about 145 feet above the minimum generation level. The storage volume for Lake Powell was 15.39 million acre-feet at the end of July, which is about 63 percent of capacity.

Weather and Other Conditions Lake Powell elevation peaked for water year 2017 at 3,635 feet in July, and will decrease to an elevation of about 3,630 feet by the end of the water year.

Desert Southwest Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.30 0.20 60.29 79.00 20.40 11.75 282,630 282,630 378,811 290,888 5,020 $165,459 $165,459 $165,459 Nov 16 4.80 2.60 54.10 78.00 20.31 11.90 345,830 373,020 363,391 374,705 1,919 $90,031 $64,805 $65,277 Dec 16 8.10 8.50 73.53 63.00 20.44 12.31 254,600 268,015 372,094 277,597 13,258 $388,103 $289,603 $510,168 Jan 17 11.50 16.00 93.88 126.00 20.59 12.80 284,450 253,225 395,966 255,068 21,520 $535,169 $535,169 $800,974 Feb 17 15.10 21.00 110.31 148.00 20.62 13.11 328,350 292,965 390,077 268,179 2,595 $0 $0 $83,974 Mar 17 18.90 22.00 102.80 99.00 20.40 13.00 558,800 504,200 531,483 496,001 12,330 $72,840 $391,582 $330,814 Apr 17 19.40 21.00 84.98 94.00 20.25 12.70 524,735 524,735 571,605 537,707 4,094 $93,243 $93,243 $112,012 May 17 7.90 11.00 59.42 40.00 20.36 12.45 487,280 487,280 571,204 491,336 22,788 $595,658 $595,658 $777,754 Jun 17 0.00 1.00 26.38 18.00 20.56 12.26 467,615 467,615 537,300 466,470 8,885 $582,202 $582,202 $687,310 Jul 17 0.00 1.10 66.54 88.00 20.47 12.27 462,330 462,330 548,865 465,914 14,972 $904,397 $904,397 $1,130,449 Aug 17 Sep 17 Total 3,996,620 3,916,015 4,660,796 3,923,866 107,381 $3,427,102 $3,622,118 $4,664,191 Actual generation as a percentage of average: 84.2% Cost per MWh: $43.44

Lake/Reservoir Levels Lake Mead’s elevation was 1,079 feet at the end of July, about 141 feet below the full storage level and about 129 feet above the new minimum generation level of 950 feet. Lake Mead started the water year with a minimum elevation of 1,076 feet in October and reached a peak elevation of 1,090 feet in February.

Rocky Mountain Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 138.60 177.30 3.85 4.66 93,769 98,500 82,866 90,186 56,146 $1,918,912 $1,768,512 $1,371,457 Nov 16 120.30 145.10 3.85 4.72 57,639 59,762 78,718 56,073 88,908 $3,104,240 $3,033,840 $2,226,606 Dec 16 268.10 160.50 98.80 106.40 3.82 4.69 91,252 93,448 101,061 102,574 73,018 $2,601,536 $2,534,336 $2,020,033 Jan 17 417.90 452.40 96.60 114.70 3.79 4.67 108,118 110,236 111,274 127,252 33,352 $2,062,592 $1,995,392 $1,205,222 Feb 17 849.60 1,170.80 96.30 173.50 3.79 4.79 97,795 99,700 99,585 129,713 4,671 $1,254,624 $1,193,824 $143,568 Mar 17 1,105.20 1,524.90 159.00 293.50 4.13 4.70 124,712 136,697 118,178 191,665 0 $785,728 $401,728 $0 Apr 17 1,342.80 1,552.90 250.20 462.40 3.85 4.50 135,854 164,886 138,114 246,662 4,244 $1,295,328 $367,328 $55,309 May 17 1,231.50 1,441.80 696.50 1,120.10 4.19 4.41 217,579 252,286 197,941 245,430 8,104 $0 $0 $116,918 Jun 17 304.70 579.90 1,124.80 2,054.20 4.76 5.78 231,289 311,890 244,139 300,898 2,747 $0 $0 $68,880 Jul 17 Aug 17 Sep 17 Total 1,158,006 1,327,404 1,171,877 1,490,453 271,190 $13,022,960 $11,294,960 $7,207,993 Actual generation as a percentage of average: 127.2% Cost per MWh: $26.58

Lake/Reservoir Content The overall reservoir content at the end of July was 121 percent of average.

Weather and Other Conditions The Loveland Area Projects (LAP) area remained drought free during July, but the trend was for drier conditions in some areas. In August, the National Weather Service forecast indicated August through October temperatures are more likely to be above normal, and the precipitation is just as likely to be above as below normal in Wyoming and eastern Colorado while more likely to be above normal west of the Continental Divide in Colorado.

Note: July hydro data and related information are not currently available for WAPA’s Rocky Mountain Region (RMR). This page will be updated and a final hydro conditions report will be distributed when the data is available.

Sierra Nevada Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 336.00 561.00 5.26 4.66 121,000 146,000 163,000 100,955 56,052 $1,179,286 $1,179,286 $1,536,064 Nov 16 4.76 3.00 399.00 706.00 5.21 4.99 104,000 34,000 104,000 42,525 57,080 $1,139,734 $1,139,734 $1,582,259 Dec 16 9.09 6.00 1,046.00 1,621.00 5.72 5.63 79,000 19,000 143,000 115,177 54,748 $1,179,286 $1,179,286 $1,280,611 Jan 17 27.78 30.00 1,167.00 3,436.00 6.13 6.43 78,000 293,000 163,000 385,479 32,534 $499,500 $499,500 $643,343 Feb 17 27.78 45.00 1,339.00 5,725.00 6.71 7.68 139,000 300,000 195,000 439,436 19,673 $479,520 $479,520 $579,856 Mar 17 28.22 46.00 1,553.00 2,574.00 7.46 8.61 290,000 330,000 207,000 399,223 26,567 $539,460 $539,460 $642,682 Apr 17 25.77 42.00 1,380.00 2,758.00 7.88 9.29 431,000 426,000 288,000 426,215 20,089 $499,500 $499,500 $555,974 May 17 27.87 17.00 1,303.00 2,259.00 7.91 9.66 526,000 516,000 442,000 617,375 11,820 $519,480 $519,480 $582,074 Jun 17 0.00 2.00 804.00 1,320.00 7.49 9.51 537,000 522,000 440,000 469,577 31,382 $519,480 $519,480 $845,693 Jul 17 451.00 623.00 6.71 8.98 539,000 564,000 524,000 438,703 40,530 $499,500 $499,500 $899,558 Aug 17 Sep 17 Total 2,844,000 3,150,000 2,669,000 3,434,666 350,477 $7,054,746 $7,054,746 $9,148,113 Actual generation as a percentage of average: 128.7% Cost per MWh: $26.10

Lake/Reservoir Content As of July 31, accumulated inflow for the water year was 172 percent of the 15-year average for Trinity, 187 percent for Shasta, 291 percent for Folsom, and 282 percent for New Melones. Reservoir storage as of the same date was 120 percent of the 15-year average for Trinity, 131 percent for Shasta, 144 percent for Folsom, and 153 percent for New Melones.

Weather and Other Conditions As of July 31, cumulative precipitation of the Northern Sierra Eight Station Index was at 186 percent of average for the date. The May 1 forecast for the 50 percent exceedence case is the basis for the official year type declaration, which is "wet" for this water year.

Upper Great Plains Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.20 0.40 8,092.00 5,601.83 55.94 58.67 569,606 558,761 868,863 561,879 146,071 $4,699,887 $4,916,797 $3,414,114 Nov 16 3.80 1.40 7,411.00 5,690.87 54.83 58.32 644,937 573,277 826,179 581,212 160,538 $4,375,658 $5,808,858 $3,233,177 Dec 16 7.10 5.60 6,468.00 5,454.05 54.23 57.60 633,647 636,181 648,173 636,090 228,602 $6,822,627 $6,771,937 $5,588,539 Jan 17 10.30 7.80 6,659.00 5,727.89 54.03 57.50 666,182 657,318 745,987 632,199 273,824 $4,853,151 $5,023,264 $5,901,618 Feb 17 12.90 12.70 6,300.00 5,706.99 54.34 58.54 568,000 569,823 646,404 503,036 358,448 $4,759,045 $4,738,596 $5,997,559 Mar 17 15.80 14.80 8,219.00 7,544.34 56.08 59.94 679,733 632,412 718,685 648,481 196,697 $2,140,470 $2,713,970 $3,499,958 Apr 17 15.10 16.00 8,052.00 9,087.27 56.95 60.50 1,022,700 1,023,820 778,900 894,351 25,646 $1,032,790 $1,044,144 $274,598 May 17 6.60 6.50 9,692.00 10,815.22 58.22 61.97 1,114,646 1,104,515 794,995 983,787 10,759 $308,233 $329,579 $57,898 Jun 17 0.60 0.20 11,809.00 12,545.36 60.45 63.67 1,194,980 1,169,724 814,641 1,137,220 1,120 $54,138 $65,770 $20,263 Jul 17 10,764.00 10,522.78 60.42 63.24 1,192,301 1,222,587 920,579 1,158,064 * $2,367 $995 * Aug 17 Sep 17 Total 8,286,731 8,148,417 7,763,406 7,736,319 1,401,705 $29,048,366 $31,413,911 $27,987,724 Actual generation as a percentage of average: 99.7% Cost per MWh: $19.97

Lake/Reservoir Content As of August 21, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 89.0 percent and 98.8 percent full, respectively.

Weather and Other Conditions The July runoff in the upper basin was 101 percent of normal, and runoff in the Garrison reach was 124 percent of average due to the abundant mountain snowpack. All other reaches were well below average. Drought conditions are present in all states of the Missouri River Basin and over a majority of the upper Basin. In Montana, 82 percent of the state is impacted by drought, and 24 percent is impacted by Extreme (D3) and Exceptional (D4) Drought with the most severe conditions present over the northeastern quarter of the state. In North Dakota, 94 percent of the state is impacted by drought, and 46 percent is impacted by D3 and D4 Drought mostly in western North Dakota. In South Dakota, 100 percent of the state is impacted by drought, and 15 percent is impacted by D3 and D4 Drought with the most severe conditions in north central South Dakota. Two units at Fort Randall are out of service through the summer due to cable tray replacements.

6 WESTERN AREA POWER ADMINSTRATION HYDRO CONDITIONS AND PURCHASE POWER REPORT September 2017

Due to the lack of current hydro data and related information for a Western Area Power Administration (WAPA) Region, this September 2017 hydro conditions report is being issued in preliminary form without an agency-wide data table or narrative summary. A final report with the table and summary will be distributed at a later date when all current Regional data is available.

Colorado River Storage Project

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.30 0.20 514.42 381.00 15.01 12.68 248,012 340,536 382,430 384,045 64,165 $6,704,081 $1,491,591 $1,683,280 Nov 16 4.80 2.60 474.23 383.00 14.91 12.31 230,952 315,541 388,155 334,811 127,238 $7,549,826 $2,850,078 $3,213,841 Dec 16 8.10 8.50 362.96 300.00 14.86 11.80 270,310 445,186 437,962 460,333 48,822 $7,692,571 $1,292,373 $1,282,528 Jan 17 11.50 16.00 361.45 359.00 14.98 11.36 355,138 431,244 457,394 455,508 57,227 $4,412,679 $1,231,482 $1,678,096 Feb 17 15.10 21.00 392.01 555.00 15.99 11.22 265,647 387,432 390,580 393,646 61,657 $5,024,221 $1,531,108 $1,555,701 Mar 17 18.90 22.00 666.27 1,110.00 16.77 11.36 272,465 405,609 390,170 458,176 29,840 $5,517,603 $1,111,921 $644,587 Apr 17 19.40 21.00 1,057.14 1,607.00 16.74 12.15 250,695 404,074 397,861 427,891 10,935 $3,468,325 $93,697 $210,181 May 17 7.90 11.00 2,337.68 2,377.00 16.30 13.67 320,070 572,228 501,886 553,204 86,530 $2,044,585 $1,990,190 $1,455,945 Jun 17 0.00 1.00 2,668.50 3,115.00 16.00 15.41 337,289 607,167 585,467 592,541 2,885 $2,301,440 $22,746 $44,051 Jul 17 0.00 1.10 1,093.88 1,073.00 15.88 15.39 436,357 505,605 612,093 556,270 4,635 $708,807 $70,408 $97,798 Aug 17 0.00 1.00 496.08 446.00 15.68 14.95 429,891 556,396 554,076 555,562 3,979 $1,004,331 $3,076 $67,921 Sep 17 Total 3,416,827 4,971,017 5,098,074 5,171,987 497,913 $46,428,468 $11,688,670 $11,933,929 Actual generation as a percentage of average: 101.4% Cost per MWh: $23.97

Lake/Reservoir Levels Lake Powell’s elevation was 3,631 feet at the end of August, about 69 feet below the maximum reservoir level and about 141 feet above the minimum generation level. The storage volume for Lake Powell was 14.95 million acre-feet at the end of August, which is about 61 percent of capacity.

Weather and Other Conditions Lake Powell elevation peaked for water year 2017 at 3,635 feet in August, and will decrease to an elevation of about 3,630 feet by the end of the water year.

Desert Southwest Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.30 0.20 60.29 79.00 20.40 11.75 282,630 282,630 378,811 290,888 5,020 $165,459 $165,459 $165,459 Nov 16 4.80 2.60 54.10 78.00 20.31 11.90 345,830 373,020 363,391 374,705 1,919 $90,031 $64,805 $65,277 Dec 16 8.10 8.50 73.53 63.00 20.44 12.31 254,600 268,015 372,094 277,597 13,258 $388,103 $289,603 $510,168 Jan 17 11.50 16.00 93.88 126.00 20.59 12.80 284,450 253,225 395,966 255,068 21,520 $535,169 $535,169 $800,974 Feb 17 15.10 21.00 110.31 148.00 20.62 13.11 328,350 292,965 390,077 268,179 2,595 $0 $0 $83,974 Mar 17 18.90 22.00 102.80 99.00 20.40 13.00 558,800 504,200 531,483 496,001 12,330 $72,840 $391,582 $330,814 Apr 17 19.40 21.00 84.98 94.00 20.25 12.70 524,735 524,735 571,605 537,707 4,094 $93,243 $93,243 $112,012 May 17 7.90 11.00 59.42 40.00 20.36 12.45 487,280 487,280 571,204 491,336 22,788 $595,658 $595,658 $777,754 Jun 17 0.00 1.00 26.38 18.00 20.56 12.26 467,615 467,615 537,300 466,470 8,885 $582,202 $582,202 $687,310 Jul 17 0.00 1.10 66.54 88.00 20.47 12.27 462,330 462,330 548,865 465,914 14,972 $904,397 $904,397 $1,130,449 Aug 17 0.00 1.00 99.68 94.00 20.34 12.41 362,615 362,615 512,355 370,861 36,996 $2,334,718 $2,334,718 $2,158,555 Sep 17 Total 4,359,235 4,278,630 5,173,151 4,294,726 144,377 $5,761,820 $5,956,836 $6,822,746 Actual generation as a percentage of average: 83.0% Cost per MWh: $47.26

Lake/Reservoir Levels Lake Mead’s elevation was 1,081 feet at the end of August, about 138 feet below the full storage level and about 131 feet above the new minimum generation level of 950 feet. Lake Mead started the water year with a minimum elevation of 1,076 feet in October and reached a peak elevation of 1,090 feet in February.

Rocky Mountain Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 138.60 177.30 3.85 4.66 93,769 98,500 82,866 90,186 56,146 $1,918,912 $1,768,512 $1,371,457 Nov 16 120.30 145.10 3.85 4.72 57,639 59,762 78,718 56,073 88,908 $3,104,240 $3,033,840 $2,226,606 Dec 16 268.10 160.50 98.80 106.40 3.82 4.69 91,252 93,448 101,061 102,574 73,018 $2,601,536 $2,534,336 $2,020,033 Jan 17 417.90 452.40 96.60 114.70 3.79 4.67 108,118 110,236 111,274 127,252 33,352 $2,062,592 $1,995,392 $1,205,222 Feb 17 849.60 1,170.80 96.30 173.50 3.79 4.79 97,795 99,700 99,585 129,713 4,671 $1,254,624 $1,193,824 $143,568 Mar 17 1,105.20 1,524.90 159.00 293.50 4.13 4.70 124,712 136,697 118,178 191,665 0 $785,728 $401,728 $0 Apr 17 1,342.80 1,552.90 250.20 462.40 3.85 4.50 135,854 164,886 138,114 246,662 4,244 $1,295,328 $367,328 $55,309 May 17 1,231.50 1,441.80 696.50 1,120.10 4.19 4.41 217,579 252,286 197,941 245,430 8,104 $0 $0 $116,918 Jun 17 304.70 579.90 1,124.80 2,054.20 4.76 5.78 231,289 311,890 244,139 300,898 2,747 $0 $0 $68,880 Jul 17 Aug 17 Sep 17 Total 1,158,006 1,327,404 1,171,877 1,490,453 271,190 $13,022,960 $11,294,960 $7,207,993 Actual generation as a percentage of average: 127.2% Cost per MWh: $26.58

Lake/Reservoir Content The overall reservoir content at the end of July was 121 percent of average.

Note: July and August hydro data and related information are not currently available for WAPA’s Rocky Mountain Region (RMR). This page will be updated and a final hydro conditions report will be distributed when the data is available.

Sierra Nevada Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 336.00 561.00 5.26 4.66 121,000 146,000 163,000 100,955 56,052 $1,179,286 $1,179,286 $1,536,064 Nov 16 4.76 3.00 399.00 706.00 5.21 4.99 104,000 34,000 104,000 42,525 57,080 $1,139,734 $1,139,734 $1,582,259 Dec 16 9.09 6.00 1,046.00 1,621.00 5.72 5.63 79,000 19,000 143,000 115,177 54,748 $1,179,286 $1,179,286 $1,280,611 Jan 17 27.78 30.00 1,167.00 3,436.00 6.13 6.43 78,000 293,000 163,000 385,479 32,534 $499,500 $499,500 $643,343 Feb 17 27.78 45.00 1,339.00 5,725.00 6.71 7.68 139,000 300,000 195,000 439,436 19,673 $479,520 $479,520 $579,856 Mar 17 28.22 46.00 1,553.00 2,574.00 7.46 8.61 290,000 330,000 207,000 399,223 26,567 $539,460 $539,460 $642,682 Apr 17 25.77 42.00 1,380.00 2,758.00 7.88 9.29 431,000 426,000 288,000 426,215 20,089 $499,500 $499,500 $555,974 May 17 27.87 17.00 1,303.00 2,259.00 7.91 9.66 526,000 516,000 442,000 617,375 11,820 $519,480 $519,480 $582,074 Jun 17 0.00 2.00 804.00 1,320.00 7.49 9.51 537,000 522,000 440,000 469,577 31,382 $519,480 $519,480 $845,693 Jul 17 451.00 623.00 6.71 8.98 539,000 564,000 524,000 438,703 40,530 $499,500 $499,500 $899,558 Aug 17 350.00 452.00 6.05 8.34 445,000 515,000 402,000 420,428 42,722 $539,460 $539,460 $708,381 Sep 17 Total 3,289,000 3,665,000 3,071,000 3,855,094 393,198 $7,594,206 $7,594,206 $9,856,494 Actual generation as a percentage of average: 125.5% Cost per MWh: $25.07

Lake/Reservoir Content As of August 31, accumulated inflow for the water year was 171 percent of the 15-year average for Trinity, 184 percent for Shasta, 286 percent for Folsom, and 277 percent for New Melones. Reservoir storage as of the same date was 122 percent of the 15-year average for Trinity, 137 percent for Shasta, 149 percent for Folsom, and 154 percent for New Melones.

Weather and Other Conditions As of August 31, cumulative precipitation of the Northern Sierra Eight Station Index was at 186 percent of average for the date. While there was no measurable precipitation in July, August had 0.06 inches. The May 1 forecast for the 50 percent exceedence case is the basis for the official year type declaration, which is "wet" for this water year.

Upper Great Plains Region

Snowpack Lake/Reservoir Purchase (Inches in Snow Lake/Reservoir Inflow Content Power Water Equivalent) (Thousand Acre-Feet) (Million Acre-Feet) Generation (MWh) (MWh) Purchase Power Expenses (Dollars) Projected Most Projected Most Median Actual Average Actual Average Actual Dry Probable Average Actual Actual Dry Probable Actual Oct 16 1.20 0.40 8,092.00 5,601.83 55.94 58.67 569,606 558,761 868,863 561,879 146,071 $4,699,887 $4,916,797 $3,414,114 Nov 16 3.80 1.40 7,411.00 5,690.87 54.83 58.32 644,937 573,277 826,179 581,212 160,538 $4,375,658 $5,808,858 $3,233,177 Dec 16 7.10 5.60 6,468.00 5,454.05 54.23 57.60 633,647 636,181 648,173 636,090 228,602 $6,822,627 $6,771,937 $5,588,539 Jan 17 10.30 7.80 6,659.00 5,727.89 54.03 57.50 666,182 657,318 745,987 632,199 273,824 $4,853,151 $5,023,264 $5,901,618 Feb 17 12.90 12.70 6,300.00 5,706.99 54.34 58.54 568,000 569,823 646,404 503,036 358,448 $4,759,045 $4,738,596 $5,997,559 Mar 17 15.80 14.80 8,219.00 7,544.34 56.08 59.94 679,733 632,412 718,685 648,481 196,697 $2,140,470 $2,713,970 $3,499,958 Apr 17 15.10 16.00 8,052.00 9,087.27 56.95 60.50 1,022,700 1,023,820 778,900 894,351 25,646 $1,032,790 $1,044,144 $274,598 May 17 6.60 6.50 9,692.00 10,815.22 58.22 61.97 1,114,646 1,104,515 794,995 983,787 10,759 $308,233 $329,579 $57,898 Jun 17 0.60 0.20 11,809.00 12,545.36 60.45 63.67 1,194,980 1,169,724 814,641 1,137,220 1,120 $54,138 $65,770 $20,263 Jul 17 10,764.00 10,522.78 60.42 63.24 1,192,301 1,222,587 920,579 1,158,064 2,924 $2,367 $995 $96,343 Aug 17 9,775.00 9,460.01 58.83 62.04 1,154,495 1,153,358 947,063 1,130,901 * $62,490 $64,611 * Sep 17 Total 9,441,225 9,301,775 8,710,469 8,867,220 1,404,629 $29,110,856 $31,478,522 $28,084,067 Actual generation as a percentage of average: 101.8% Cost per MWh: $19.99

Lake/Reservoir Content As of September 13, the active conservation pools for the Canyon Ferry and Yellowtail Dams were 82.9 percent and 98.1 percent full, respectively.

Weather and Other Conditions The August runoff in the upper basin was 129 percent of normal. Runoff at Fort Peck was 78 percent of normal, with Oahe and Fort Randall well above normal due to 150 percent of average precipitation. Drought conditions are present in all states of the Missouri River Basin and over a majority of the upper Basin. In Montana, 90 percent of the state is impacted by drought, and 40 percent is impacted by Extreme (D3) and Exceptional (D4) Drought with the most severe conditions present over the northeastern quarter of the state. In North Dakota, 60 percent of the state is impacted by drought, and 22 percent is impacted by D3 and D4 Drought mostly in the western half. In South Dakota, 69 percent of the state is impacted by drought, and 6 percent is impacted by D3 and D4 Drought with the most severe conditions in north central South Dakota. Two units at Fort Randall remain out of service due to cable tray replacements.