Chesapeake Energy bills itself as “America’s Champion of Natural Gas” and is one of the most active independent operators drilling in the United States.
Operations in the Eagle Ford are focused on 449, 000 net acres with net production of 105,000 BOE/DAY (updated 11/15)
The Chesapeake – CNOOC joint venture announced in October 2010 brought the Chinese into one of America’s hottest plays. CNOOC paid Chesapeake $2.16 billion or $10,800 per acre for a 33% interest in 600,000 net acres at the time of the deal. CNOOC also has an option to participate with a 33.3% share in additional acreage and the development of midstream infrastructure with Chesapeake. Chesapeake and CNOOC target the Eagle Ford Shale play’s oil window at depths of 5,000-11,000 ft with horizontal wells that have an additional 5,000-8,000 ft average lateral length.
Chesapeake is the most active company drilling wells in many of these areas and controls much of its own mid-stream, compression, drilling and oilfield service assets. Chesapeake came onto the scene in the Eagle Ford as the company began leasing acreage in the oil window in August 2009 and accumulated over 600,000 net acres. In July of 2013, Chesapeake sold 55,000 net acres to EXCO Resources for $680 million
The company’s stock is traded on the NYSE under the symbol CHK. Chesapeake’s headquarters is in Oklahoma City, OK. In South Texas, Chesapeake has field offices in Carrizo Springs, San Antonio, Victoria, and Zapata. Chesapeake Energy develops onshore U.S. natural gas and oil reserves in the Barnett Shale (North Texas), Bossier (Louisiana), Eagle Ford Shale and Pearsall Shale (South Texas), Haynesville Shale (East Texas and Louisiana), Marcellus Shale (Appalachian Region of Ohio, Pennsylvania, and West Virginia), and Niobrara Shale (Colorado and Wyoming).
Eagle Ford Shale Oil & Gas Discussion Forum
Join the Eagle Ford Discussion Group today – your voice counts! Mineral Rights Forum is a discussion network for mineral owners, royalty owners and industry professionals to discuss oil & gas related topics.
Counties Where Chesapeake is Active
- Atascosa County
- Dimmit County
- Duval County
- Frio County
- Goliad County
- LaSalle County
- McMullen County
- Washington County
- Webb County
- Zavala County
Chesapeake Eagle Ford Shale Quarterly Commentary
Chesapeake did not report specifically on its Eagle Ford operations for the Third quarter. Other highlights include:
- Enhanced operating and capital efficiencies drive 2016 third quarter average production of 638,100 boe per day
- Oil production of 86,600 barrels per day lower sequentially after divestiture impacts of 8,200 barrels per day in the 2016 third quarter; 2016 fourth quarter oil production projected to be 90,000 to 95,000 barrels per day
- Decrease in production expenses of $0.25 per boe sequentially, resulting in lower full-year 2016 and 2017 production expense guidance
- Improved financial flexibility following refinancing of near and mid-term maturities through new offerings and subsequent tender offers
- Enhanced operating flexibility through Barnett Shale exit, Mid-Continent and Rockies gathering agreement restructuring and significant reductions of future midstream commitments
- Total liquidity following Barnett Shale closing of approximately $3.7 billion
- Over 60% and 50% of projected natural gas and oil production, respectively, hedged in 2017
- Exit rate production, driven by oil volumes, poised to grow significantly in 2017 and 2018
Chesapeake has been at the forefront of oil and gas litigation across the country including being named in several lawsuits alleging underpayment of royalties in Arkansas, Louisiana, Ohio, Oklahoma, Pennsylvania and Texas.
- January: the Fort Worth school district was awarded $1 million when Chesapeake improperly deducted expenses from royalties owed to the district and its taxpayers. The suit involved at least 30 leases on land covering at least 1,000 acres.
- February: the Texas Supreme Court upheld a lower court’s ruling to award at least $1 million in royalties, interest and attorney fees to the Hyder family who had been fighting Chesapeake Energy since 2010.
- May: Chesapeake agreed to pay Fort Worth $15 million to settle a lawsuit that claimed the company owed $33.5 million in royalty payments from more than 260 leases on about 5,800 acres of city property in Tarrant and Johnson counties.
- April: the Michigan Attorney General reached an agreement with Chesapeake that included setting up a $25 million fund to pay residents who say they were defrauded by the company.
- September: The U.S. Department of Justice announced it has opened an investigation into possible antitrust violations by Chesapeake Energy Corp.
During a second quarter earnings call, Chesapeake executives said that their focus on cost and technology improvements on their high quality assets have allowed them to remain competitive.
Chesapeake announced they have slashed the cost to drill Eagle Ford wells that are 9,000 feet long by 50%, down to $4 million. This savings will allow them to increase their drilling program for the rest of the year in the Eagle Ford. During the quarter, they also reduced the time to drill down to 9.7 days.
Eagle Ford net production averaged approximately 97 thousand barrels of oil equivalent (mboe) per day (210 gross operated mboe per day) during the 2015 fourth quarter, a decrease of 10% sequentially. Production during the 2015 fourth quarter was impacted by plant downtime that averaged 2 mboe per day. Average completed well costs to date in 2015 (through October) are $5.4 million with an average completed lateral length of 6,250 feet and 23 frac stages, compared to the full-year 2014 average completed well cost of $5.9 million with an average completed lateral length of 5,850 feet and 18 frac stages. The company placed 18 wells on production during the 2015 fourth quarter, compared to 123 wells in the 2014 fourth quarter, and plans to place approximately 170 to 180 wells on production in 2016. Chesapeake’s operated rig count in the Eagle Ford averaged three rigs in the 2015 fourth quarter, and the company anticipates releasing all operated rigs in the area by June.
Chesapeake has planned 2016 total capital expenditures ranging from $1.3 to $1.8 billion, approximately 57% lower than 2015 levels
Chesapeake reported a net loss of $4.695 billion in the third quarter in contrast to a 3% year over year production increase. The company highlighted their focus on organizational and operational initiatives to face the extended low commodity price environment.
For Chesapeake’s Eagle Ford Shale operations, net production averaged approximately 108 thousand barrels of oil equivalent (mboe) per day, an increase of 3% sequentially. Other Eage Ford highlights include:
- Average completed well costs to date in 2015 are $5.3 million, compared to $5.9 million for 2014.
- Average completed lateral length of 6,000 feet, compared to 5,850 feet for 2014
- Averaged three rigs in the 2015 third quarter, and the company anticipates maintaining three operated rigs through the end of the year.
- Significant efficiencies with longer laterals and larger completions in the area
- Expecting approximately 9% production growth this year compared to 2014
- Currently have 19 wells drilled with greater than 9,000 foot laterals including two record 13,000 foot laterals
Chesapeake Energy Corp reported second quarter results amidst speculation about the viability and future of the company. Like many other shale drillers over the past year, Chesapeake is struggling. Prolonged crude prices and legal trouble are taking its toll and for the second straight quarter the company is reporting a huge net loss. For Q2, the loss is $4.151 billion.
Eagle Ford Highlights include year-to-date well costs are down 12% from the 2014 average to $5.2 million per well. Also:
- Production decreased by 7% this quarter to average approximately 105 thousand barrels of oil equivalent (mboe) per day. The company blamed the decrease on a facility that was out of commission for more than 60 days, but as the facility was brought back online, the company reports an all-time production high of 127,000 BOE per day in July
- Chesapeake expects to spud its first upper Eagle Ford well in the 2015 third quarter
- Operated rig count in the Eagle Ford averaged six rigs in the 2015 second quarter, down from 20 a year ago, and the company anticipates maintaining three operated rigs for the second half of the year.
For first quarter of 2015, Chesapeake Energy announced a net loss of $3.8 billion and boasting of new technological innovations. Chesapeake’s loss is even more staggering when compared to the company’s net income of $374 million one year ago. The company plans to slash drilling and completions over the rest of the year. They expects to complete fewer than 50 wells in the fourth quarter of 2015 and will drop their rig count from 40 down to about 15.
Eagle Ford net production averaged approximately 113 thousand barrels of oil equivalent (mboe) per day, an increase of 7%. Other highlights include:
- Well cost-reductions: the company anticipates completed well costs of $5.5 million by year-end 2015
- Successfully drilled five wells with laterals in excess of 10,000 feet
- Successfully completed down spacing tests in various sections of its acreage, adding 600 – 700 incremental locations to its undrilled inventory
- Plans to test its first Upper Eagle Ford well in the 2015 fourth quarter
- The drilling team broke several records including drilling their deepest well with a total measured depth of just under 21,000 feet, fastest spud-to-rig-release time of 7.8 days, and lowest drilling cost well at $1.1 million
May 7, 2014 Chesapeake’s Eagle Ford net production averaged ~88,000 boe/d (187,000 gross operated boe/d) during the first quarter of 2014. First quarter production was adversely impacted by temporary downtime at gas gathering and processing facilities, operated and competitor offset activity-related shut-ins and weather-related activity reductions. Company officials say these issues have lessened during April and May, and Chesapeake is projecting a higher sequential quarterly growth trajectory for Eagle Ford production during the remainder of the year. Approximately 64% of the company’s Eagle Ford production in the 2014 first quarter was oil, 15% was NGL and 21% was natural gas. Chesapeake operated an average of 18 rigs and connected 81 gross wells to sales during the first quarter of 2014 in the play, compared to 12 average operated rigs and 65 gross wells connected to sales during the fourth quarter of 2013. 81 wells were put online in the Eagle Ford during the first quarter of 2014 – average production was approximately 885 boe/d from these wells. As of March 31, 2014, Chesapeake had 945 producing wells and 114 wells awaiting pipeline connection or in various stages of completion in the Eagle Ford.
August 1, 2013 In the Eagle Ford Shale play, Chesapeake connected 140 wells to sales during the 2013 second quarter, which was substantially more than the 111 wells connected during the 2013 first quarter. Net production during the 2013 second quarter averaged approximately 85,000 boe/d (190,000 gross operated boe/d). This represents an increase of 135% year over year and 14% sequentially. The average peak daily production rate of the 140 wells that commenced first production during the 2013 second quarter was approximately 900 boe/dy. Approximately 66% of the company’s Eagle Ford production during the 2013 second quarter was oil, 14% was NGL and 20% was natural gas. Chesapeake is currently operating 15 rigs in the Eagle Ford and, due to reduced cycle times and the sale discussed above, plans to reduce its operated rig count to 10 by the end of 2013. Average spud-to-spud cycle time during the quarter was 16 days, down from 21 days year over year. As of June 30, 2013, Chesapeake had drilled a total of 963 wells in the Eagle Ford, which included 795 producing wells, 24 additional wells waiting on pipeline connection and 144 wells in various stages of completion.
May 1, 2013 Chesapeake continues to generate strong liquids production growth rates from its Eagle Ford Shale play in South Texas. Net production during the 2013 first quarter averaged 75,000 boe/d (166,000 gross operated boe/d). This represents an increase of 225% year over year and 20% sequentially. Approximately 65% of the company’s Eagle Ford production during the 2013 first quarter was oil, 18% was NGL and 17% was natural gas. As of March 31, 2013, Chesapeake had drilled a total of 887 wells in the Eagle Ford, which included 650 producing wells, 34 additional wells waiting on pipeline connection and 203 wells in various stages of completion. The company is currently operating 15 rigs in the play and plans to reduce its operated rig count to 13 rigs in the second half of 2013. Spud-to-spud cycle times during the quarter were 18 days, down from 25 days year over year. Chesapeake plans to have substantially all of its core Eagle Ford acreage held by production by the end of 2013. The average peak daily production rate of the 111 wells that commenced first production during the 2013 first quarter was approximately 950 boe/d. Chesapeake is in the process of selling a portion of its northern Eagle Ford Shale leasehold and producing assets which are outside of its core development area.
February 21, 2013 Chesapeake continues to generate impressive liquids production growth rates from its 485,000 net acres of leasehold in the Eagle Ford Shale in South Texas. Net production during the 2012 fourth quarter averaged 62,500 boe/d (143,200 gross operated boe/d). This represents an increase of 266% year over year and 20% sequentially. Approximately 66% of total Eagle Ford production during the 2012 fourth quarter was oil, 15% was NGL and 19% was natural gas. As of December 31, 2012, Chesapeake had 534 gross operated producing wells in the Eagle Ford, of which 405 reached first production in 2012, including 98 in the fourth quarter. The company is currently operating 17 rigs in the play, down from a peak of 34 rigs in April 2012, and plans to operate an average of 16 rigs in 2013. Spud-to-spud cycle times have declined dramatically in the Eagle Ford, from 26 days in the 2011 fourth quarter to only 18 days in the 2012 fourth quarter. Chesapeake plans to drill fewer Eagle Ford wells in 2013 than in 2012; however, the planned number of wells turned-to-sales will be roughly equal in both years. The company remains on pace to have substantially all of its core and Tier 1 Eagle Ford acreage held by production by the end of 2013. Of the 98 wells that commenced first production in the 2012 fourth quarter, 90 wells (or 92%) had peak production rates of more than 500 boe/d, including 27 wells (or 28%) with peak rates of more than 1,000 boe/d.
November 1, 2012 Chesapeake’s activity on 490,000 net acres of leasehold in the Eagle Ford Shale in South Texas continues to drive strong results. The play yielded net production of 52,200 boe/d (120,500 gross operated boe/d) for the third quarter of 2012. This represents an increase of 371% year over year and 44% sequentially, which included an increase in oil production of 462% year over year and 48% sequentially. Approximately 68% of total Eagle Ford production during the 2012 third quarter was oil, 14% was NGL and 18% was natural gas. As of September 30, 2012, CHK had 441 gross company operated producing wells in the Eagle Ford play, which included 124 wells that reached first production in the 2012 third quarter, compared to 121 in the 2012 second quarter and 40 in the 2011 third quarter. Also, Chesapeake had approximately 233 Eagle Ford wells drilled, but not yet producing. Recent efficiency gains in drilling cycle times will allow the company to achieve its targeted well count goal utilizing fewer rigs than would have been required in 2010-12. The company is currently operating 23 rigs in the play, down from a peak of 34 rigs in April 2012 and plans to exit the year at 22 rigs. The company is currently on pace to have essentially all of its core and Tier 1 Eagle Ford acreage held by production by the 2013 fourth quarter. Of the 124 wells which commenced first production in the 2012 third quarter, 115 wells (or 93%) had peak production rates of more than 500 boe/d, including 43 wells (or 35%) with peak rates of more than 1,000 boe/d, continuing a trend of steady operational improvement during the past year. Three notable recent wells completed by CHK in the Eagle Ford during the quarter are as follows:
- The Faith-Yana A Unit C1H in Dimmit County, TX achieved a peak rate of approximately 2,175 boe per day, consisting of 1,580 bbls of oil, 295 bbls of NGL and 1.8 mmcf of natural gas per day;
- The Gates 010-CHK-B 1286-D3H in Webb County, TX achieved a peak rate of approximately 2,100 boe per day, consisting of 660 bbls of oil, 655 bbls of NGL and 4.7 mmcf of natural gas per day; and
- The Shining Star Ranch B 1H in La Salle County, TX achieved a peak rate of approximately 1,580 boe per day, consisting of 1,450 bbls of oil, 80 bbls of NGL and 0.3 mmcf of natural gas per day.
As part of its “core of the core” strategy, Chesapeake is currently pursuing the sale of a portion of its existing leasehold and producing assets outside its current core development area in the Eagle Ford play.
August 8, 2012 Chesapeake’s Eagle Ford Shale assets continue to drive strong results, yielding net production of 36,300 barrels of oil equivalent (boe) per day (gross 75,400 boe per day) for the 2012 second quarter, an increase of 615% year over year and 58% sequentially, which included an increase in liquids production of 745% year over year and 71% sequentially. Approximately 66% of total Eagle Ford production during the 2012 second quarter was oil, 17% was NGL and 17% was natural gas. Production growth in the play has been augmented by the continued build out of new compression facilities and new pipelines as well as securing additional short-term truck transportation for oil production. Chesapeake expects price realizations to improve by approximately $5 per bbl beginning in October 2012 as new oil gathering pipelines and other infrastructure are completed. As of June 30, 2012, Chesapeake had 337 producing wells in the Eagle Ford play, which included 121 wells that reached first production in the 2012 second quarter, compared to 62 in the 2012 first quarter and 27 in the 2011 second quarter. Also, as of June 30, 2012, Chesapeake had approximately 220 Eagle Ford wells drilled, but not yet producing, that were in various stages of completion and/or waiting on pipeline connection. Recent efficiency gains in drilling cycles of well spud to rig release and well spud to first sales, as well as reductions in service costs, have resulted in cost savings of approximately 15% per well in the Eagle Ford. As a consequence of this greater drilling efficiency, the company is planning to reduce its drilling activity in the Eagle Ford from 28 rigs currently to 25 rigs by December 2012 and plans to average 22 rigs during 2013. Of the 121 wells which commenced first production in the 2012 second quarter, 110 wells (or 91%) had peak production rates of more than 500 boe per day, including 37 wells (or 31%) with peak rates of more than 1,000 boe per day. Three notable recent wells completed by Chesapeake in the Eagle Ford during the quarter are as follows:
- The Gates 010-CHK-B TR1-D6H in Webb County, TX achieved a peak rate of approximately 2,070 boe per day, consisting of 710 bbls of oil, 665 bbls of NGL and 4.2 mmcf of natural gas per day;
- The Holubar Dim C 2H in Dimmit County, TX achieved a peak rate of approximately 1,900 boe per day, consisting of 1,730 bbls of oil, 110 bbls of NGL and 0.4 mmcf of natural gas per day; and
- The Foley MCM A 1H in McMullen County, TX achieved a peak rate of approximately 1,500 boe per day, consisting of 1,335 bbls of oil, 55 bbls of NGL and 0.6 mmcf of natural gas per day.
May 2, 2012 Eagle Ford Shale (South Texas): Chesapeake’s activities in the Eagle Ford Shale continue to generate strong results as the company further delineates its 475,000 net acre leasehold position. Approximately 30% and 40% of the company’s 2012 and 2013 drilling budgets, respectively, have been allocated to the Eagle Ford Shale. The Eagle Ford Shale is setting company production records on a weekly basis. Last week, we produced more than 55,000 barrels of gross operated crude. That’s a gain of 30,000 barrels of oil since January 1 of this year, which is an increase of 120% in just 4 months. We are currently producing gross operated 75,000 BOE per day in this outstanding play. Approximately 55% of total Eagle Ford production during the 2012 first quarter was oil, 20% was natural gas liquids (NGL) and 25% was natural gas. Year to date, Chesapeake’s gross operated oil production in the Eagle Ford Shale has more than doubled from 25,000 bbls per day at the beginning of 2012 to approximately 55,000 bbls per day at the end of April 2012. The growth has been achieved as a result of increased infrastructure and takeaway capacity as well as improved lateral steering, enhanced stimulation optimization and increased operational efficiencies. We have made improvements in our stimulation and completion processes, resulting in higher production without added cost. In fact, we were able to lower per well costs by approximately 15% due to faster drilling times and lower stimulation costs. During the 2012 first quarter, the company brought on line more than 60 wells, including eight wells with peak rates of more than 1,000 bbls per day of oil. The company has secured pipeline transportation capacity for all of its projected Eagle Ford shale oil production with pipeline projects scheduled to become operational between May 2012 and January 2013 which will enable significant transportation cost savings relative to truck transportation alternatives. During the 2012 first quarter, approximately $150 million of Chesapeake’s drilling costs in the Eagle Ford were paid for by its JV partner, CNOOC. Chesapeake is currently operating 35 rigs in the play and plans to average 30 rigs in 2012. Three wells highlighted by Chesapeake in the quarter included:
- The McKenzie D 3H in McMullen County achieved a peak rate of 1,390 b/d oil, 60 b/d of NGL and 0.6 mmcf/d of natural, or approximately 1,540 boe/d
- Blakeway Unit B Dim 1H in Dimmit County achieved a peak rate of 1,200 b/d oil, 90 b/d NGL and 0.8 mmcf/d of natural gas , or approximately 1,420 boe/day
- The Lazy A Cotulla M 3H in Dimmit County achieved a peak rate of 1,020 b/d oil, 35 b/d of NGL and 0.3 mmcf/d of natural gas, or approximately 1,115 boe/d
February 22, 2012 Total net production, from the Eagle Ford, averaged over 17,700 BOE per day in Q4 2011. That’s up 60% versus Q3 and 370% year-over-year. Our current gross operated production from the play is 45,500 boe/d and 22,600 boe/d on a net basis. Our production mix in this play is approximately 50% crude, 20% NGLs and 30% natural gas. We continue to be very pleased by our performance in the Eagle Ford, and it’s a driving force behind our liquids production growth targets in the months and years ahead. To date, we have 108 wells that tested with peak oil rates of 500 b/d or more. And that’s not an equivalent basis, that’s black oil in the tanks. We are producing 178 wells in the play to date and have a backlog of almost 200 additional wells to be completed and connected in the coming months. This will fuel our production ramp-up through the end of the year and into ’13. We finished 2011 with 7 frac crews running in the Eagle Ford and will be up to 11 by mid-March of this year and 13 by the end of 2012. We’ve also doubled our drilling efficiency in the play since January 2010 based upon drilling feet per day to now approximately 725 feet per day. And this has driven down our days/well and helped reduce costs. And great progress has been made in building and restructuring the play with the addition of 350 miles of pipeline during the year. We expect to gain greater transportation capacity as 80 more miles of pipeline and regional rail and loading terminals are put in. And we also are adding 85 oil hauling trucks from Chesapeake’s very own trucking company within Thunder Oilfield Services. These actions help ensure that our oil moves to markets that give us the highest oil price possible.
November 3, 2011 Chesapeake has four plays that resulte in more than 900 mmboe back to the company. “They would be the Eagle Ford, where we own 460,000 net acres; the Mississippi Lime play in Northern Oklahoma and Southern Kansas, where we own 1.4 million net acres; the Cleveland Tonkawa play in the Anadarko Basin, where we own 750,000 net acres; and now the Utica, where we own 1.35 million net acres after our JV sale. Collectively, the potential of these plays, net to Chesapeake shareholders, is over 4.3 billion barrels of oil equivalent. And by the way, our net leasehold cost in those plays is now only $100 per net acre. For example, in the Eagle Ford, we’ve only lately have had kind of a surge of production there because we were waiting on a lot of infrastructure. We just, I think, did a pretty good job of modeling for that. And you don’t see us miss our numbers and then blame unforeseen circumstances. We plan for those and take it in stride. And, again, through our balanced and diversified asset base, we can have issues in one area and not affect our overall performance.” Press Release July 29, 2011 “…Yes, I think when you look at the Eagle Ford, you see the best rates of return in the wet gas window. It’s got a lot of energy and got a lot of hydrocarbon stuck — stacked into place.” “Eagle Ford Shale. First Chesapeake production was in 2010. Our current gross operated production is 20,000 barrels of oil equivalent, making us the fourth largest producer in the play to date…” Source: Chesapeake Energy Corporation Press Release May 3, 2011 “We still have — and I’ll let Steve jump in here too. But we have lots of logistics issues in the Eagle Ford where we are limited by the amount of oil that we can produce. And so we have a whole lot of oil shut in, and maybe Steve has more.” “And there is a lot of bottlenecks associated with trucking, part of it was also completion prohibitions during the dear hunting season over the winter. And so we were able to get some oils drilled but a lot didn’t get completed until the spring. So we should have a very good quarter in the second quarter.” Source: Chesapeake Energy Corporation