Newfield Briefs Initial Results from Eagle Ford Assessment Program
Newfield Exploration disclosed initial results from its Eagle Ford Shale assessment program. Since mid-2010, the Company has drilled and completed 11 Eagle Ford wells on its 335,000 net acre position in Maverick, Dimmit and Zavala Counties, Texas.
"We are excited about the success of our 2010 assessment program. Our early assumptions that the Maverick Basin would hold thick, high-quality Eagle Ford pay and offer us the opportunity to develop a major new resource play are proving true," said Lee K. Boothby, Newfield Chairman, President and CEO. "All of our initial Eagle Ford assessment wells found light oil and confirmed an active petroleum system and producible oil and gas across a vast area. We will continue with our active drilling program and, with continued success, be in position to substantially increase our investment levels in the play in the second half of 2011."
The 2010 assessment program had two key objectives:
- To confirm the presence of hydrocarbons, the distribution of fluid types and the resource potential across the acreage through core samples, fluid sampling, comprehensive logging and long-term production data;
- To satisfy all lease obligations while completing initial wells with a consistent fracture stimulation program.
All 11 Eagle Ford wells had lateral lengths of approximately 5,000 feet and encountered light oil with API gravities ranging from 30 – 50 degrees. Newfield now believes that substantially all of its Eagle Ford acreage in the Maverick Basin is within the oil window.
Newfield has more than 30 days of production on six of the wells completed to date. Peak gross production rates (24-hour) ranged from approximately 400 – 900 BOEPD with an average of 630 BOEPD. Thirty-day gross production averaged approximately 400 BOEPD. Two recent completions have less than 30 days of production. The first well recently commenced production at approximately 860 BOEPD gross and the second is cleaning up following recent fracture stimulation.
Three of the 11 wells drilled to date had ineffective stimulations and/or mechanical issues. Although all were productive, results were not indicative of the full geologic or production potential.
Estimated ultimate recoveries (EUR) for wells drilled with more than 90 days of production range from 200 – 400 MBOE. Newfield estimates that oil in place on the Company's acreage in the Lower Eagle Ford ranges from 40 – 60 MMBOE per section. The Company owns an approximate 85% working interest in 523 sections.
The success of the 2010 program and expectations for further optimization has contributed to 2011 plans which have the following objectives:
- To advance the understanding of development spacing and recovery factors through pilot programs;
- To improve initial production rates and EUR per well by optimizing fracture stimulations;
- To maintain lease positions and satisfy drilling commitments, a minimum of a two-rig drilling program.
In late 2010, Newfield signed an agreement with a major service company to ensure that the necessary frac spreads and personnel are available to meet completion needs in the Eagle Ford in 2011 and 2012.
In addition to its assessment of the Eagle Ford, Newfield drilled two Pearsall Shale wells in 2010 and completions are planned in the first quarter of 2011. In late 2010, Newfield acquired operatorship and an additional 50% working interest in the Pearsall Shale from its co-venturer. As a result, Newfield now owns an approximate 85% working interest in all depths across its position.
Newfield entered the Maverick Basin in early 2010 through an acreage acquisition. The Basin is prospective in multiple geologic horizons ranging from 3,000 – 12,000 feet. In addition to the Lower Eagle Ford Shale, other horizons include the Austin Chalk, Upper Eagle Ford, Georgetown, Glen Rose, Pearsall Shale and Sligo.
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