Total natural gas and oil production from the six most prolific Lower 48 unconventional basins is expected to increase between July and August, the Energy Information Administration (EIA) said Monday in its Drilling Productivity Report.
Natural gas volumes/rig, led by the Marcellus Shale, are forecast to increase by 0.425 Bcf/d between July and August,
The federal agency reviewed drilling data through June and then extrapolated projected production through August for six key tight/shale oil and gas regions: Bakken, Eagle Ford, Haynesville and Marcellus shales; Niobrara formation and Permian Basin.
The six regions accounted for 95% of U.S. oil production growth and all domestic natural gas growth during 2011-2013, EIA said. In every region, new-well gas and new-well oil production/rig has risen since August 2013 and is expected to increase through August.
The report uses recent data on the total number of drilling rigs in operation, as well as estimates of drilling productivity and estimated changes in output from existing wells to estimate changes in oil and gas production. The method doesn’t distinguish between oil-directed and gas-directed rigs because once a well is completed, it may produce both; more than half of the wells do that.
In the Bakken, gas production from one average rig should hit 527 MMcf/d in August from 519 MMcf/d in July. Oil output is seen rising to 516 b/d from 510 b/d. Since 2007, EIA said, Bakken gas output has risen by more than 20 MMcf/d, while oil output is higher by about 17,000 b/d.
Eagle Ford gas production from this month through August from one average rig is expected to be 1,307 MMcf/d, up from 1,294 MMcf/d. Oil output from the Texas play is seen rising by 4 b/d from one average rig between July and August, or 483 b/d from 479 b/d.
In the Haynesville, which is spread across East Texas and Northern Louisiana, EIA said monthly additions from one average rig should be 82 MMcf/d higher from July through August, or 5,402 from 5,320 MMcf/d. Oil output should be flat at about 23 b/d.
Marcellus gas output per average rig is seen up 46 MMcf/d month/month, or 6,598 MMcf/d in August from 6,552. Oil output is forecast to be flat at around 30 b/d. The Niobrara should post solid gas gains per rig, at about 26 MMcf/d, or 1,648 MMcf/d from July’s expected 1,622. Oil production/rig in the Niobrara is seen rising by 8 b/d to 380 b/d in August from July’s 372 b/d.
The Permian’s gas output/rig is forecast to rise by 3,000 MMcf/d between July and August to 301,000 MMcf/d from 298,000 MMcf/d. Oil output from one average rig should be up by about 2 b/d to 150 b/d in August from 148 b/d in July.
Month/month additions are estimated for “one average rig,” representing EIA’s forecast of an average rig’s contribution to production from new wells. The estimate uses several months of data on total output from new wells for each field, divided by the region’s monthly rig count, lagged by two months.
In response to the EIA report, BNP Paribas analyst Teri Viswanath, who directs the firm’s natural gas commodity strategy, noted what the gas gains, particularly in the Marcellus, are doing to the market. EIA’s estimate of supply growth, along with known transportation constraints, has led to increasing price weakness in the Appalachian Basin this summer, she said.
“The common range for Dominion, South Point prices last Friday ranged from $1.98 to $2.25/MMBtu, which means that a few fortunate buyers actually spent less than $2.00 for their gas…”
Gas supplies from North America “should naturally price at parity with Henry Hub,” she said. “However, we have experienced prolonged periods when stranded supply prices as an extraordinary discount. This occurred with our Rockies supply and once again is occurring with the development of the Appalachian resources.
“Indeed we see the potential that rising Marcellus production is poised to permanently disrupt the traditional Gulf-based pricing paradigm…With the eastern half of the U.S. market increasingly dependent on the Appalachian Basin, we see the possibility that a new supply proxy for this region will emerge. If verified, Henry Hub may well be relegated as a supply proxy for only the Gulf and western markets.”
© 2021 Natural Gas Intelligence. All rights reserved.
ISSN © 2577-9877 | ISSN © 2158-8023 |