Saturday, February 9, 2008
Spacing – not exactly the 640 acres we had heard. The size of the spacing unit for a particular reservoir is set according to its depth and production characteristics. The larger the frac needed the larger the unit of land needed.
There is excitement in the gas industry over the ability to drill horizontally. A drilling rig can go vertically and then extend that drill to the side.
If people have not been approached there is time for them. The play keeps expanding.
Cosmic Seismic Services of Canada does the majority of the seismic testing in this area.
Atty. Dale Tice of Greevy Assoc. Williamsport
A well should be 500’ from any structure on a person’s property that contains living area.
Marcellus Shale is above the Onondaga , a layer of dense limestone that outcrops in NY and PA. Forced pooling is allowed above the Onondaga. A group of landowners may group themselves together voluntarily to negotiate a lease.
These landowners do not have to be adjoined. Each property owner in a group will have their own lease. One size may not fit all. Those same landowners may not be pooled together for the purpose of drilling for gas. To be pooled, the company gathers the land that has the potential to be above gas reservoirs. It can be the whole of one property or a portion. They will gather as much land is as necessary and form it into a unit. There may be several wells drilled in that unit. A unit is guided by production.
The horizontal drilling can be used with pooled properties.
Timber – it is best to get an independent appraisal for any timber for which you request payment.
Water – Make certain you have an independent entity take a water sample three months before drilling. Water can be drawn from any pond, lake, stream on a leased property. Check your addendum on this.
Roadways – make sure you address this in any addendums. Whose concern are they before and after the drilling.
Fences – Who is liable to replace. Make sure they fence off their well area so no one can enter.
Make certain that any seismic work has your pre-consent.
Pugh Clause – a bit murky to this writer. Make certain your attorney explains as it is important if you are in a pooled unit. In lay terms (I think) at the end of your lease, only the portions of your land in that pooled unit shall continue to be held by the lease. At any rate, check this one out with an atty.
Record and Audits - make certain you can review this information.
Should you sign a lease? It depends on: your goals for the property, your financial strength, your estate plans, the terms of the lease.
Should you not sign a lease? It depends on: do not sign because the neighbors did, because you are afraid they will drill across property lines, if you do not understand the effect on you, your family and your property, for the bonus dollars alone.
How to make a decision – Understand all terms of the lease, seek an attorney that works for you and makes you feel comfortable with asking questions.
The lease covers two different terms : Primary in which the do their exploration and seismic studies. There is little impact on property. Risk in this term – abandonment of lease – no gas under your ground. Poor lease terms, poor work relationship, assignment of lease to others with whom you are not comfortable. Think about the impact and negotiate terms that work for you.
Secondary in which there is well drilling and production. There is more impact. How much impact? As much as they need: well site – could be viable for years, access roads, pipelines, metering stations, compressor buildings (all mobile and not subject to Planning Commission), traffic for routine maintenance. If no well is drilled at the end of the term, make certain the addendum states that the lease is ended.
Financial Gain is a balancing act. Consider your property risk, resale and taxes.
Make certain you understand how much Royalty you might receive. There are many factors, the least of which is the percentage.
Have a clear understanding with your accountant before you sign any lease. After is not the time to make changes. You will pay tax. Just as you need a gas attorney you need someone that understands gas taxes. Do-it-yourself tax programs might not give you all the information you need.
Pipelines – Eminent Domain cannot be used for wells. Probably not for small pipelines but maybe for the large ones.
15% is the new plateau. Work toward that number.
Wednesday, February 6, 2008
Money In the Ground John Orban III
Oil and Gas Production in Non Technical Language, Martin Raymond and William Leffler
example in Let's Talk an Oil Deal Association for Tax Purposes - basically when two or more taxpayers are associated in a common undertaking if it looks like a corporation it can be taxed as such.
My questions? Does this include pooled properties or those in a unit? Should we add an accountant to the mix of experts?
Tuesday, February 5, 2008
Members of the core group attended the second workshop at Penn State Lehman Campus on February 4th.
Sunday, February 3, 2008
Small comment from the blog person: My concern over gas leasing has its genesis in our experience with being landlords. Recent history – My mother left us a little rancher in
Saturday, February 2, 2008
Unit Size- how units are decided or declared?
Answer: That is a very good question and one we are still waiting from the state to legally define according to PA law.
It depends on how deep the well actually goes. Shallower wells are controlled by one set of state laws and deeper wells by a different set (Conservation Law). Since we don’t actually know how deep the wells will be it is kind of an educated guess as to which set will apply. You can go on the PA web site and read the regulations. I questioned Joe Umholtz, Chief, Bureau of Oil and Gas Management Pa DEP and he was unclear too. Ed called different people in the department and was also unable to get an answer. They just forwarded us the actual law, which we had already read.
In theory the unit is supposed to be the area that the Company will be pulling the gas from. So in "shale" it should be fairly small. Historically shale would be from 30-80 acres. Deeper wells could drain larger areas. They report from 180-600 acres. The state does not determine this, the company does on its permit. There are hearings on each permit at which we could probably testify but I am not sure how much clout you or I would actually be able to carry.
The other thing that is disconcerting to me is the clause in PA law that allows spacing orders to be no larger than 10 square miles. WOW! That’s 6400 acres
But just because we don't have an exact answer in PA law that is clear to us doesn't mean we should take a wait and see out look. We feel that we should limit that size in our leases. We already have limits on size to no more than 640 acres from Whitmar, New Penn, and Apex Oil. Their language is good.
So it all boils down to the same thing; if the Township, County can't regulate it which they can't and we are unsure what protections the State offers we better protect our selves in our lease agreement.
Gas well spacing is ideally an economic question. It is a trade off of the increased cost of tighter spacing, more wells per area, and cost of money in the future due to a longer time to drain the gas. In these very tight shales needing huge frack jobs, the extend of the fractures may be even more important to spacing. The rate of flow declines, obviously, over time as the pressure declines. It is an exponential declining value. After a gas well is completed, flow and pressure build-up tests are completed. With very complicated equations and some known factors from past wells in the same formation, the rate of flow and gas volume can be estimated. Even the extent of reasonable drainage area may be calculated. In
As with much of this blog, information has come through the
Also Ross Smith Energy Group RSEG, Instinct ,LLC
Players – Range Resources, Atlas Energy Resources, Southwestern Energy, EDG Resources, Equitable Resources,
CNX Gas, Penn Virginia, Ultra Petroleum, (possibly) Phillips Petroleum and PetroEdge have drilled horizontals in
Favorable Properties – High TOC – Total Organic Carbon, Adequate thermal maturity, Significant gas in place, Thickness, Favorable mineralogy, Overpressured, Successful high-rate gas wells.
Immediate post-fracture clean-up is a contributing factor to success. Frac fluid must be cleaned up immediately. Disposal of frac fluids will become an operational issue. There are only three disposal wells in the Commonwealth.
The Marcellus may be stronger in the NE than in the SW due to thicker, deeper shale, more brittle with a higher TOC. Companies are still negotiating 1/8th royalties.
Friday, February 1, 2008
The paragraphs in blue were written by people in Wayne County. The black at the bottom contains local information and is current. Needless to say, water must be considered in our addenda.
I have an added comment about this well water issue and the drilling. Stop to think a moment. They will not be using ground water as a source it is just not practical. If the drilling of a gas well requires a minimum of 1 million gallons it would take way to long to get that from a water well. A very good well could put out 50 gallons per min. even at that rate it would take 2 weeks to get the water tankers filled to drill just one well. Its not efficient to get the water this slowly.
They will not be pumping out of a ground well. They will be taking it from a surface source of water some where. Time is money for these drilling teams and they wont be sitting around for 2 weeks to fill their tanks.
Ask around in other areas. Its not coming out of a well. They will pump it from a surface source or pay someone to pump it out of their pond or lake, stream or river.
Does the water quality group know that the energy companies are going to try to use lakes, ponds and streams to pull water for the fracing? Long Consulting/Chesapeake basically told us that at the Jan 9 meeting. They do not play to drill water wells for fracing. They still may drill wells for other purposes and in any event the current domestic wells must be tested and the aquifer protected from infiltration of hydrocarbons and toxics. Also the use of surface water, I would presume, would be controlled by the addenda.
It has been said time and time again, by the DEP, that the permitted party would be responsible to correct any problems associated with the drilling of the well. The DEP has specific procedures it follows when notified of any infractions. Though it has been said the gas companies have vested interest to do the best job possible, environmentally speaking, there have been instances where something has gone wrong.
On a brighter note it seems the cement casing is responsible for less destruction and contamination of the aquifers.
Water testing should be done (seasonally) before the well is drilled. It's standard operating procedure for the gas companies to test the water before they start drilling.
Anyway, at some point in the process the wells are fractured with water.
The O&G people say they use about 1 million gallons (about 40 tractor trailer tankers) to accomplish this. As far as I know, this process is complete on the county's 3 existing wells. The good news is that they can, and do, recycle the water from one well to the next. They simply truck it. At XXX they pulled the water from the creek, by the dairy barn. It's taken out over a period of several days; a small percentage of the total flow. At some point the water needs to be disposed of and they need to truck it to a willing sewer plant. They pay the plant operator a fee based on gallons. the last I heard from O&G they were still looking for an interested local sewer plant.