Nevada Bureau Of Mines And Geology

The main differences should be shown to help better protect the environment, never to harm or destroy it. These skills are also essential so that one can understand the view point of the others and also put across one’s ideas in a better manner. Sticking with the TMS, whether you decide to land the lateral above or below the rubble zone going forward, would it uniformly apply to all of the leasehold or would 1 method work better in different parts of the play? If you normalize that piece out as best we can, we’re coming up with about a normalized 45-day cycle time from spud to when we PDP in the lateral. But certainly 30 days from TD, which is the frac-ing the wells for 90 days spud to sales is certainly a real possibility. I think we are targeting kind of 75 to 90 days depending on when we can get the frac in place. So I would say, probably 75 days, 60 to 75 days from now, at least a time to start looking. But time will tell. Any concern that over time that, that might be an area that would be difficult to keep propped open or too early to tell?

At Equinor we have built a culture centered around software craftsmanship, open source and sharing knowledge. And you’d mentioned that based on the results of the Ash well, you think you’re pretty confident that you can frac through that rubble zone, you may have some microseismic, maybe a suggest as well. The Anderson 17-2 is below the rubble zone, the Anderson 17-3 is above the rubble zone, so they’re opposite. Both those Anderson wells are drilled above the rubble zone and how are those going to be completed? But we would be looking at somewhat of a slightly higher target to avoid the potential presence of that in the wells going forward. David, it’s twice the amount of fluid volume than what we’ve pumped on the Crosby and twice the amount of fluid is obviously going to take a lot longer to produce off. David, this is Rob. Robert C. Turnham – President, Chief Operating Officer and Non-Independent Executive Director And Dan, this is Rob, I might add. Although management might respect the covenant, there is no real motivation to prevent them from implementing their own agenda.

My question is, aren’t there other countries that are producing helium? Usually, we see some tightness in inventories but distillates, for example, are almost 40 million barrels more than what they were for the same time frame last year. So yes, we’re excited about what we’re seeing and just need to see some more history. And certainly, extremely optimistic with what we’re seeing. This pricing session saw us lose four cents against the US dollar and that figure is central in figuring out price changes. George Murphy keeps you informed of fuel pricing issues, making sure you’re ahead of Big Oil’s pricing curve! We have great flexibility to just flip our allocation between the Eagle Ford and TMS if we continue to see equal or greater rates of return in the TMS. They’re experimenting around and trying different techniques to see what works the best. And their thought was they would remain active in the second half, but waiting to see how many rigs would be running in the play. I don’t see the entire population of the earth banding together any time soon. We don’t know — we don’t have enough data points to know whether or not the “rubblelized zone” is present throughout the entire acreage block.

Again 1 or 2 months doesn’t exactly make the entire picture. A roustabout or roughneck could easily take home as much as a typical mid-level department manager of a multi-national corporation while getting as much as 6 months off every year. Once we get past, I guess, these several wells that EnCana’s currently drilling or completing, what do you think industry activity looks like for the second half of the year based on current permits? 100 million allocation next year. 50% to nearly 13 million b/d. And then just lastly, what’s the current LOE OpEx requirements for the TMS wells? Richard M. Tullis – Capital One Southcoast, Inc., Research Division Just following up on Dan’s questions on the TMS timing. Okay, great. And then one last one. And the way we model it is there’s a fixed cost and then a variable cost. And then I guess on the Smith well, in terms of the frac-ing procedure, you’re looking to do more of the larger fracs as you did on the Ash or what’s kind of the plan there?