I believe the Continental well Larry mentioned is the Lambakis 1-11H in the S.E. corner of Grady County. They are reporting 4.2 Million cft. & 110 bopd. My little piece is just across the line In Stephens County. Continental has applied for a pooling order for our section. They also have an “intent to drill” in the township directly north of us in Garvin County.
Not sure but in Continental Resources second Quarter report they had had drilled a well that extended the Cana 25 miles. Our well in Dewey county was mentioned completed at 2.1 millions cubic feet gas per day and and 165 bopd. You can check for drilling permits in McClain County on the Corporation Comm Web site. You can even narrow down to the section. Good Luck Larry
Just joined the group. Being from Chickasha I have an interest in what is going on in Grady County. Own a few mineral acres there. I finished OU in 1958 with a degree in Geology and cut my teeth on the Anadarko Basin. I am still in the business and generate prospects for sale in South Texas. This Woodford Shale development should be very interesting to follow and I appreciate having access to a group such as this. Good luck to all.
Cheryl, if you will click on the discussion above at the top of the discussion list titled “Update on Wells around Calumet” you will find a pdf attachment. That attachment shows the wells around Calumet. If your section is not on that map then you can go to the Oklahoma Corporation Commissions website and search for your minerals using your legal description. Here is a link to that site. http://www.occpermit.com/WellBrowse/
The last time I was out there about 2 weeks ago all three rigs were still drilling in section 35, 13N, 9W.
thank you Gary, I checked out that site, it looks a little complicated for me…not exactly sure how it reads. Glad to hear the 3 rigs are drilling.
I joined the group as I am an out of state mineral rights owner and wanted to keep up with the activity in Canadian County…My attention was caught by the picture posted by Gary of 35/13/9…and the 3 rigs drilling there…is anyone near there and knows the progress? Or anything else going on around there? Thanks
@Andy Lark, I saw on the occ database that Charter Oak Prod. has applied for a pooling order for McClain County Sec 8/6N/4W
Intresting info about about the Woodford. Here is a link to the article and I pasted it below.
http://stocks.investopedia.com/stock-analysis/2011/Woodford-Shales-…
Woodford Shale’s Popularity On The Rise
Posted: Aug 22, 2011 09:52 AM by Eric Fox
The development of the Woodford Shale moved steadily forward during the second quarter of 2011, with most activity focused on areas that have a high content of liquid hydrocarbons. Operators have been busy working to delineate the extent of the play, building infrastructure to handle future production, and trying to determine the down spacing potential of acreage here.
Cana Woodford Delineation
Continental Resources (NYSE:CLR) is focused on the Cana area of the Woodford Shale as wells here produce a significant content of liquids along with the natural gas stream. The company has 270,000 net acres under lease in the Woodford Shale, and estimates that 33% of this leasehold is in the Cana portion of the play.
Continental Resources just reported a number of successful wells in the Cana Woodford Shale, including one well that was 25 miles south of any previous Woodford Shale activity. The company believes that this well proves up an additional 15,000 net acres held by the company.
Continental Resources is operating 13 rigs in the Cana Woodford Shale and has indicated that the play will be a significant area of focus for the company going forward. (Find out how to take advantage of this market without having to open a futures account. For more, see A Guide To Investing In Oil Markets.)
Down Spacing Potential
Cimarex Energy (NYSE:XEC) has 120,000 net acres prospective for the Cana play and has been active here since 2007, drilling 100 net wells to date.
During the second quarter of 2011, Cimarex Energy worked on a pilot project to determine how far down the core area can be down spaced. If the company is correct that the acreage can be developed economically on 80-acre spacing, then it would yield 730 net locations for Cimarex Energy.
Infrastructure Expansion
Devon Energy (NYSE:DVN) has 243,000 net acres under lease in the Cana http://stocks.investopedia.com/stock-analysis/2011/Woodford-Shales-…Woodford and is one of the most aggressive operators in developing acreage here. The company plans to drill 225 wells in 2011, compared to only 87 wells in 2010.
Devon Energy is also expanding the capacity of a natural gas processing plant that serves this area. The Cana gas processing plant was damaged by a tornado in May 2011, and is expected to be operational by the fourth quarter of 2011.
Devon Energy has allocated $125 million to increase capacity at the plant from 200 million to 350 million cubic feet per day. The extra capacity will be complete and operational in the fourth quarter of 2012.
QEP Resources (NYSE:QEP) has been involved with the Woodford Shale and has been adding acreage in the liquids area of this play. The company plans to operate three rigs in this play for the remainder of 2011.
QEP Resources has been working on perfecting the company’s drilling and completion process during the second quarter of 2011, and reported an increase in the estimated ultimate recovery of Cana Woodford wells.
QEP Resources has increased the company’s capital allocation to the Woodford and plans to spend 11% of its 2011 capital budget in this play, up from 7% in 2009.
**The Bottom Line
**The Woodford Shale doesn’t get as much attention in the media as some other unconventional resource plays in the United States, but operators are rapidly increasing development due to the high liquid content of wells here. (For more on oil production and shortfalls, see Peak Oil: What To Do When The Well Runs Dry.)
I was out at Calumet this weekend. I talked to a guys and he said they are doing seismic work on 125 sq mi. Let’s hope that means they will be doing a lot more drilling!! Here is a link to the company doing the work. http://www.dawson3d.com/about/whatwedo.html
Don Underwood who is a member of this group posted this to the Grady Co group. I found it interesting and informative. http://www.mineralrightsforum.com/group/grady-county-ok-oil-gas/for…
I can add a little bit to GAry’s comment in terms of timing because that is part of what I do-process and interpret 3D seismic data. I don’t have any idea when the data collection started but 125 sq miles is a fair size 3D survey in what is probably an area with numerous farms, houses, water wells and fences. It will take the seismic crew sometime to permit, layout the listening devices and do the data collection. I would guess about 45 days or more.
Then the processing of the data has to be done so the various people who interpert the data will have the best product to determine well site locations. I would think that will take a minimum of 60 days or more.
After the geophysical interpreters get the data they will integrate known geological conditions in and around the survey and make their decisions on where to drill. If there are expiring leases that the survey covered some wells could be staked within about 30 days of the interpreter getting the data. If additional leases are to be taken based on the survey that would probably happen pretty quickly, also within 30 days.
So, if the survey started today, a royalty owner is probably looking at 4 to 6 months to see any “action” in terms of new leasing or newly staked wells based on the 3D survey. That will not preclude any companies or individuals who do not have access to the 3D survey from doing their own business in the area of the survey concerning taking leases and drilling wells.
I’m interested in information regarding Blaine County, OK Section 19-15-10
I understand a well was started a couple of weeks ago, but that’s about all I know. Can anyone tell me a ballpark time frame it takes to drill a well and then for it to begin producing? Does the leasing company contact you to let you know if the well was successful or a dry well? Does that area show promise from previous wells?
We have owned interests in a few sections in Blaine County for a long time, but they’ve never generated much interest until recently. Consequently, we’ve never tried to learn much regarding our interests, but think it’s time to start learning. So here I am basically starting from scratch. Any ideas, suggestions, or old fashioned schooling would be really appreciated!! Thanks for your time!
It took about 3 months to drill and complete our well (from drilling to production). I think that is pretty fast. It will more than likely take longer, especially with the lack of frac water now. It also depends on how far you are from the pipeline. I am not familar with that part of Blaine Co. but you can check the OCC website and enter the legals near yours to see how the wells in the area are doing. The OCC website is here http://www.occpermit.com/WellBrowse/Home.aspx
The Best way to educate yourself is to keep reading the post on this site and don’t be afraid to ask questions. There is usually someone here that can answer your questions.
Lori the drilling on our well in dewey county was done in late April but well was not completed until sometime in July. I was able to find out production because it was mentioned in Continental Resources quarterly report in early August. Corporation site does not show completion yet nor has it been in paper. Still no division papers. Not easy to get return phone calls from oil company. They are very busy. Lanrry
Thank you Gary and Larry for your responses. I’ve been reading the articles on this site and others and I appreciate your help.
Lori,
The closest completion is immediately South of you in section 30. The Schwartz 2-30 reported initial production of no oil, and 940 MCF/day. By Woodford standards, not very impressive if this is accurate, but still a decent well. However, it is possible they had problems with the lateral or the frac job. Occasionally, it happens. And sometimes production even picks up from their intial test reports.
There are several “intent to drill” sites in 15N-10W, and even more in 15N-11W.
As far as the timing goes, you are going to have to be patient. Even after they do the completion and report intial results, it will be several months before you see a check. At some later point, they will send out a division order for you to sign to confirm your interest. No one will ever tell you how the well is doing. Your only hard evidence is when you get your first check along with the production report.
On my wells, they installed Total Flow meters, and so it was possible at any point for me to drive up and check the production rates after the well was completed, and long before any checks started arriving. However, I’ve noticed that is not always possible on some of the meters.
JW, thank you for all the information. It is all very helpful and very much appreciated!
Don, the only way I know is on occ main page select divisions, oil & gas, databases. A page will come up with instructions ( it gets a little complicated at this point) on accessing databases. When you get to the search screen on top left menu 1st box select “relief sought”, in 2nd box select “equals”, in 3rd type in code # from list below such as 50=spacing, 41=pooling etc. Click add to list, click get result. The next screen will list the applications by date, you will have a choice to view old to new or new to old. Then you have to scroll through them to find what you’re looking for. It’s really a pain the first time you do it but it’s the only way I know to get almost real time information. I don’t think you can do it by well because at this point there is not yet a well to associate it with. If anyone knows an easier way please let us know!
I have been trying to work my way around the OCC web site. How do I check pooling orders and spacing orders? For instance if I just gave a township and range location how would you go about pulling up such orders that fell within that Township and Range?
Do you need to know which well is associated with such orders?
Water is in short supply in the cana woodford. This is an article from the Oklahoman.
Drought presents challenges for Oklahoma oil producers
Oklahoma oil and natural gas producers have been forced to scrounge for water this summer because of drought and continued high temperatures.
BY JAY F. MARKS jmarks@opubco.com
Published: September 2, 2011
Oil and natural gas production is a water-intensive business, so some Oklahoma companies have had to take extra steps to overcome this summer’s heat and dry conditions.
Continental Resources Inc. President Jeff Hume said water has been hard to come by during the continuing drought.
Historically, Continental has drawn water for its operations from nearby farm ponds, but the drought has made many of those disappear, Hume said. Instead, the company has had to buy well water in Oklahoma.
“It’s even worse south of us,” he said.
Still, Hume said the drought has not forced Continental to substantially alter any of its regular operations.
Officials from Chesapeake Energy Corp., SandRidge Energy Inc. and the Williams Cos. offered a similar assessment of the drought’s impact.
Farther north, Hume said, Continental has had no problem finding water in North Dakota’s Bakken Shale because that state has had plenty of rain.
GMX Resources Inc., another Oklahoma operator, has switched to a completion program in the Bakken that is less water-intensive, despite North Dakota’s record rain and snowfall, said Alan Van Horn, the company’s manager of investor relations.
He said companies increasingly are recycling water from their hydraulic fracturing operations, which use about 100,000 barrels of water per well.
“Much of the frac water that is used is recycled and used again and again,” Van Horn said.
“You obviously cannot just empty frac water once used into the bar ditches or dispose of it on the surface. So it’s trucked out and used at other frac sites or disposed of properly.”
Huge pond planned
Devon Energy Corp. is making plans to build a 500,000-barrel pond near Geary or Calumet to store produced water, which is water that comes out of the ground after wells are drilled or fractured.
Such large-scale water recycling is unprecedented in Oklahoma, so state regulators had to create a set of new rules for the Devon project.
Jim Heinze, operations engineering manager for Devon’s Mid-Continent area, said the company is looking to apply some of the lessons it learned in the Barnett Shale, a more mature basin in Texas.
He said typical storage ponds for produced water are 50,000 gallons or less, but a larger pond will allow Devon to serve multiple wells at the same time.
“We’re trying to reduce the impact that we have on the environment,” he said.
Devon spokesman Chip Minty said the company recognizes that water is a resource that must be preserved, so it pioneered efforts to conserve water in the Barnett Shale.
Devon saw the opportunity to do the same thing in 2008, he said, but it took time for the Oklahoma Corporation Commission to develop rules for what the company wanted to do.
Heinze said Devon will dig a pond that is almost as long as two football fields on each side. It will be about 10 feet deep, enough that rain won’t cause it to overflow.
Devon also will use a 60-mil liner to prevent produced water from leaking into the ground.
Heinze said Devon will use a pipeline system to move the water to and from the company’s wells, a move that will reduce truck traffic in its operating area.