"..."...Gary C. Evans - Chairman and Chief Executive Officer
Well, obviously, as we start adding on both the Marcellus and Utica wells, throughput goes up significantly. And so right now, all the gas that goes into Eureka ends up going to Mobley. And taking 30-million-a-day gas wells that are dry gas in the Mobley to be processed is crazy. So we are working with other pipeline companies to have interconnects that we can take the dry gas elsewhere….Since we're on the Western side of the Appalachia Basin, we're closer to some of the truck lines that we can -- we actually are acquiring firm transportation on so that we can begin connecting Eureka and be going West with this gas. So just to kind of give you an idea of throughput, 2012, we averaged 23 million cubic feet of gas a day….And as I mentioned, these dry gas wells in Utica is no reason to be taking dry gas to a cryogenic processing plant. ..Gary C. Evans - Chairman and Chief Executive Officer
Yes, that -- what Jim was saying on that Stalder Pad, Steve, is that what the thinking was, we've kind of decided this over the last few days, because we'd like to get that Utica well on and test it by year end, is to go ahead and just fracture-stimulate the Utica only, not the Marcellus,..because it does have different kinds of equipment-ing and delays, so that we can the Utica well on and producing. So we'll come back and frac the Marcellus well a little later...."
"...…Michael G. Moore - GPOR President and Chief Financial Officer
Well, it's certainly fair to say that we have an appetite for the dry gas window. The Irons well is a phenomenal well. And so we're really excited about the dry gas window. We think it's going to have really good returns. We have thought that for some time now. The Irons well is confirming that for us. So certainly we have a large appetite for..."
.Gary C. Evans - Chairman and Chief Executive Officer
The (Eclipse) Tippens well is located 9 miles north and east of our Stalder Pad, which, as Jim has indicated, we're drilling the pad hole and will soon drill the lateral section. We're tying that well into our Eureka Hunter Pipeline System. It will be tied in by mid-December. And that well tested at 23 million a day of dry gas. And it maxed out the production equipment that was on location. We believe the well will do better than that, and we'll know as we tie it into the Eureka Hunter System. So there's data point #1.
Data point #2 was a well just announced here over the last couple of days called the Irons well by Gulf Port. It's located just due north of our Stalder Pad and North and East of our Farley Pad. It tested at 30 million cubic feet of gas a day. So let me remind you, 30 million cubic feet of gas a day is equivalent of 5,000 barrels a day on a 6:1 ratio.
So now let's go to the south and the east...." continued
Dry Utica-GPOR and MHR comments from 4th quarter cc. (several replys)
"...James D. Palm - Chief Executive Officer and Director GPOR
In the gas phase of the play, we are pleased to announce the Gulfport recently brought online, our Irons 1-4H well, which was drilled to a full vertical depth of 9,770 feet with the a 6,629-foot horizontal lateral. The Irons well is the furthest East (SE Belmont County, Ohio in Utica Dry Gas Window) well Gulfport has drilled to date, and we are impressed with the strength of this well. The well produced, at an average, 24-hour sales rate of 30.3 million cubic feet of gas per day. I should note that the lateral on this well is shorter than many of the wells we have drilled in the play, and as you can see, this is a very strong well. We estimate approximately 44% of our acreage lies within this phase of the play. And our Irons well marks a critical data point in the development and derisking of the dry phase of the play….As we begin to focus more of our drilling on the dry gas side of the play, permits, right away and long lead items related to the construction of the dry gas system have already begun. We are working with MarkWest to ensure that we have a coordinated approach to drilling activity and pipeline availability….James D. Palm - Chief Executive Officer and Director
Neal, It is really a strong well. We're are really pleased with it. We started off with about 6,900 pounds shut-in pressure on it. The last 24 hours that we were looking at it, we were throwing well over -- we're over 30 million a day, we're going about 3,200-psi. We probably will produce it long term, someplace from 15 million to 20 million a day. We think we'll be up in the 5,000 pound flowing pressure in that, and that's kind of the basics on it. Looks really strong particularly considering that it's not that long a lateral…Michael G. Moore - President and Chief Financial Officer
"Antero recently placed on line the Gary 2H well that produced at a 24-hour peak rate of 24.2 MMcf/d of natural gas, 162 Bbl/d of condensate and 3,053 Bbl/d of NGLs assuming full ethane recovery (per current industry practice and assuming typical ethane plant product recoveries of 85% to 90%). The Gary 2H had a natural gas shrink of 16% associated with 1220 Btu wellhead gas and an oil-equivalent rate of 7,246 Boe/d (44% liquids). This rate is the fourth highest peak rate announced in the Utica Shale to date. The well is located in Monroe County, Ohio, and was drilled with a lateral length of 8,900 feet. The initial 12 horizontal Utica wells that Antero has completed and placed online to date have an average 24-hour peak rate of 5,635 Boe/d assuming ethane recovery, an average lateral length of approximately 6,500 feet, an average Btu of 1245 and an average drilling and completion cost of $12.3 million per well. Antero expects well costs to decline as well completions have access to the Company's fresh water distribution system and drilling and completion efforts are optimized..." Was pretty sure thy said in cc they went through dry Utica in this well and am pretty sure both MHR and I think PDEC or Rex or GPOR confirmed something similar
you need to go a better job at quoting and not be so inflammatory when guessing at quotes "Mr. Sample say something like "only over my dead body" to that?" Mr Semple said "It absolutely competes with Bluegrass" and he said "But I believe that there will -- at least in the near term, that there really will be only one Y grade pipeline project to the Gulf Coast developed out of the Northeast..."
this was quote from MWE second quarter 2013 cc
"...John Edwards - Crédit Suisse AG, Research Division
Okay. And then just, if you could give your thoughts on, as far as the market goes, the view that this project would be in addition to the Bluegrass Pipeline that's been proposed. And I guess any additional volume ramp-up on ATEX? Or is this being viewed more as a project that competes, say, with Bluegrass?
Frank M. Semple - Chairman of The Board of Markwest Energy GP LLC, Chief Executive Officer of Markwest EnergyGP LLC, President of Markwest Energy GP LLC, Chief Executive Officer of Markwest Hydrocarbon and President of Markwest Hydrocarbon
It absolutely competes with Bluegrass. If you look at the volume projections out of the Utica and the Marcellus, and clearly, there's a lot of variability in those forecasts, but over the course of the next 5 years, you would expect that if there is a need for transporting the C2+ Y grade to the Gulf Coast, there's probably only enough volume to support one of those 2 projects. The ATEX project, the E-P mix project that had been discussed, I don't really see this as being a major competitor. The timing of that is a little different than the in-service date for these Y grade projects that have been announced. But I believe that there will -- at least in the near term, that there really will be only one Y grade pipeline project to the Gulf Coast developed out of the Northeast..."
Msg 34453 of 34458 at 12/9/2013 5:05:19 PM from iv mlp board by
Bluegrass - open season extended
"Bluegrass Pipeline announces extension of open season
Bluegrass Pipeline, a joint venture between Williams (WMB) and Boardwalk Pipeline Partners, LP (BWP), announced that it is extending its binding Open Season until Jan. 17, 2014 at 5 p.m. CST. The extension is in response to requests of interested shippers who would like additional time to evaluate the pipeline project and the project's market outlet options. "We are pleased with the quality of interest shown thus far by producers that are active in the Utica and Marcellus shale plays. Extending our open season provides potential shippers with more time to evaluate how our proposed project fits their growing needs for NGL transport, fractionation, export and other end-use market options," stated John Haynes, senior vice president and chief commercial officer for Boardwalk Pipeline Partners.
Does this mean what I think it does? MWE certainly controls a huge part of volume from the Marcellus and Utica. Does the KMP/MWE JV have a more likely outcome as a winner?"
From an article posted on iv mlp Msg 34433 of 34442 at 12/9/2013 11:08:12 AM by
Forbes: How To Play The Shale Boom's Next Phase
"....A more conservative way to play the shale boom is by investing in master limited partnerships, which now have a new supply of projects to increase dividends. Mark Reichman, with the Houston investment banking firm Simmons & Co., says Kinder Morgan is well positioned to capitalize on growing natural gas exports, including the $200 million Sierrita project that will transport gas from Arizona to northern Mexico–and help support gas prices in the U.S. Markwest Energy Partners is building a gathering-and-processing network to collect gas from wells in the Marcellus and Utica plays in Pennsylvania and Ohio, separating out the liquids that frequently flow with it.
Reichman also recommends a handful of MLPs that are investing in crude-oil transportation, including Crestwood Midstream Partners, which this year acquired Inergy to gain access to the Bakken shale; Enbridge Energy Partners, which is building projects to move heavy crude to the Gulf of Mexico and lighter Bakken oil to East Coast refineries; and Williams Partners, with its growing infrastructure in the Marcellus and interstate pipeline system.
Williams Cos., the operator of Williams Partners, plans to spend $3.3 billion expanding its gathering system in Pennsylvania through 2015, on top of the $5 billion in dividend-producing assets it already has there.
“I’ve worked all over the country–offshore Gulf of Mexico, Texas, the Rockies–and these are the biggest wells I’ve ever seen,” marvels Ryan Savage, regional vice president in charge of pipeline operations for Williams Cos., which will carry Cabot’s gas to market. “This resource is so huge, it’s just incredible.”
first,t with the pipeline accident, the cold weather freezing off some volumes and ngls still being week it is felt this quarter will have very week distribution coverage
second, based on points in no.1 above carrying over into first quarter of 2014, plus slow ramp up in south Texas acquisition, high debt level needing some equity to be issued and rising interest rates it appears apl may struggle most of 2014 with current distribution coverage let alone growing distributions
the two projects plans will have close completion timings. SXL in "early (not sure what early means)" 2016 and KMP/MWE JV in "second" quarter 2016
in addition to Seneca 1 and Majorsville 5 already announced for 4th quarter
I recollect mwe also benefits from mariner east by it committed shipper percentage, so both KMP/MWE JV and Mariner east are winners for MWE
Msg 12507 of 12509 at 12/6/2013 10:15:34 AM from oldtimers iv board by
The following message was updated on 12/6/2013 10:16:18 AM.
In response to msg 12506 by tonoos view thread
Re: Ladenburg Thalmann - Analyst Day highlights report
" I missed much of the pres., heard something about a new partner..." - tonoos
It's not another partner.
With Cardinal now underway on the supply chain side, Navidea has decided they may be able to enhance the speed of penetration by contacting the surgical oncologists directly. Cardinal doesn't call on individual surgeons.
So Navidea plans to explore co-promotion opportunities with companies with existing sales teams that already call on surgeons. That way Lymphoseek can get pushed from both the supply side and the end-user side simultaneously.
It's discussed during the presentation around timeframe 28:00 - 31:00...
Nachrichtenquelle: Business Wire (engl.)
| 05.12.2013, 16:15
"...Enterprise Products Partners L.P. (NYSE: EPD) today announced that the process of injecting ethane into the Appalachia-to-Texas Express (“ATEX”) pipeline began in late November and will continue throughout December 2013. Commercial service is expected to begin in January 2014...."
DUG East observation. One thing that analysts and companies agreed on at the at Hart Energy’s 2013 DUG East conference was that the industry has never seen a shale play where so much success has been found so early.
Baker Hughes Rigs count for the November 15 reporting week.
PA Marcellus 55 – up 1
PA Utica 2 – unchanged
Ohio Utica 34 rigs – unchanged
WV Marcellus 32 rigs – up 1
"..Shell information looks promising. Shell Oil Co. is still actively exploring a plan to build a huge natural gas processing plant in western Pennsylvania, and may have selected engineering firms to do feasibility studies...
...But Shell has cautioned that a final decision on whether to build the multibillion dollar plant wouldn't be made for several years. While some recent media reports suggested that the project might be canceled, The Associated Press found that Shell still has scores of people working on the assessment.
Shell has an option to buy the industrial site in Monaca that's now owned by Horsehead Corp. In an early November conference call, Horsehead CEO Jim Hensler said Shell continues to be "extremely active" at the site, with "about 70 people crawling all over" it recently.
Shell spokeswoman Kimberly Wendon told the AP in an email that "our evaluation of the site continues" and that the process "typically takes several years to complete." Wendon added that the company expects a similar time frame in Monaca.
There also are other signs Shell is seriously considering the project.
Gulfport Energy Corp. said in early November that it signed a contract to provide Shell with raw natural gas for the project, if it gets built. And last month Chemical Week, an industry publication, reported that Shell has chosen two multinational engineering firms to do feasibility and pre-project planning. Executive Vice President Graham Van Hoff told the publication that Bechtel Corp. and Linde AG of Germany would do the preliminary work.
Energy experts say it's simply too early to tell whether Shell will or won't build the plant, since the final decision involves worldwide market conditions and competing projects, both within the company and by competitors. Shell CFO Simon Henry suggested in a late October conference that the company will have to choose among several large new investments over the next year or two."
from shale directories facts an rumors
first it depends the propensity of their processing type agreements (fee, pop, keep whole) and secondly is narrowing of ngl (thru ngl price improvement) to oil spread if pop and overall prices if keep whole
Intarz, do not know if it gives answer for sure, but does narrows the field considerably per prior messaging discussion. Here is quote that does not make it for sure ye,t because they have similar situation to overcome in Marcellus even though several producers have committed to them
"A major difference between the projects was that Shell produces and owns all of the natural gas it uses at the Pearl facility, but would have had to buy natural gas from the U.S. grid in order to supply the Gulf Coast project."
Posted on December 5, 2013 at 12:28 pm by Zain Shauk
HOUSTON — Royal Dutch Shell said Thursday it is abandoning plans for a massive gas-to-liquids project envisioned for Louisiana, citing poor economics for the project that was expected to cost more than $20 billion.
The plant would have turned natural gas into diesel, jet fuel and other liquids, but the company determined that it would be too costly.
“Despite the ample supplies of natural gas in the area, the company has taken the decision that GTL is not a viable option for Shell in North America, at this time, due to the likely development cost of such a project, uncertainties on long-term oil and gas prices and differentials, and Shell’s strict capital discipline,” the company said in a statement.
Shell announced the potential site for the project in September, but said it was no sure thing as the company was continuing to evaluate its economics.
“We are making tough choices here, focusing our efforts and capital on the most attractive opportunities in our worldwide portfolio, to add value for shareholders,” Shell CEO Peter Voser said in a statement.
Gulf Coast: Nation’s largest methanol plant planned for Texas
A prior Shell gas-to-liquids project in Qatar, the Pearl GTL project, cost about $19 billion and offered more value than the conceived Louisiana project, according to the company.
A major difference between the projects was that Shell produces and owns all of the natural gas it uses at the Pearl facility, but would have had to buy natural gas from the U.S. grid in order to supply the Gulf Coast project.
Shell’s decision came down to that and other costs, with the projected construction tab expected to be too high, and the margin the company hoped to earn on the natural gas it processed projected to be too low, spokeswoman Kimberly Weldon said.
Shell made its decision to abandon the project despite a $112 million incentive offered to the company by the state of Louisiana.
Wells are probably not that costly so 222 bopd is probably a fair return "The well was drilled to a lateral length of approximately 1,200 feet and was fracture stimulated with nine stages using our “Super Frac” completion design." Next well is 1500 feet