This week, the Wildgrass Master Association’s Oil and Gas Committee sent two new documents below to the Broomfield City Council.

1) Broomfield MOU Comparison with Erie and Brighton 1-3-17 - This memo provides a comparative analysis to the Broomfield City Council of the MOU provisions and regulations relative to those of the state COGCC and several nearby jurisdictions: the City of Brighton and the Town of Erie. It provides recommendations of “best management practices” that are being used by operators in other parts of the state that Broomfield should consider adopting.

2) Wildgrass proposed MOU Amendments - 3 - This document includes specific recommendations and feedback for Broomfield to consider in the MOU to better protect the residents in the northern neighborhoods and throughout Broomfield as oil and gas operations continue to be proposed throughout the county.

‍

‍

‍

Extraction's presentation began to provide some insight into the design plan of the Sheridan plan. As of now, the proposed plan for the Lowell pad has still not been made public.

‍

https://www.dropbox.com/s/tsp2ekmhc78sie9/Extraction-BroomfieldRedevelopmentPlan-Oct252016.pdf?dl=1

‍

Facility Name/Number: Dittmer KE Pad 29-032HN

Location: 447013

This is a 25 well site (to compare, the proposed Lowell pad is to be a 20 well site, the remaining three pads are to be 40 well sites). 

At this site, 9 wells have drilling permits and 13 have location status (perhaps 3 are complete?  We aren't sure why that doesn't add up to 25). Per the COGCC website, the inventory for this site is:

Condensate Tanks: 0

Gas Compressors: 6

Water Tanks: 6

Wells: 25

Separators: 30

Oil Tanks: 36

The attached pictures were taken at this site on 10/06/16. 

‍

This section will be updated as new WOGc meeting minutes are available

• July 20, 2016

Matthew Sura,
Oil and Gas Attorney
specializing in representing landowners and mineral owners
(720)563-1866 /  mattsura.law@gmail.com

To drill a well, the oil and gas operator would like to acquire, through purchase, lease, or agreement, the right to extract the oil and gas accessed by the well.  But what if there is one mineral owner in that area who does not want to allow drilling?  Then the operator has the ability to apply to the Colorado Oil and Gas Conservation Commission (COGCC) to “force pool” the reluctant mineral owner – thereby allowing the mineral development to go forward.  The force pooling laws are found in C.R.S. §34-60-116 and COGCC Rule 530.  

Forced pooling is often threatened by landmen to persuade reluctant mineral owners to lease their minerals.  But the threat of forced pooling should not be used to pressure a mineral owner to hastily sign a lease.   Forced pooling is only used as a last resort for operators who have already acquired leases to the vast majority of acreage they are planning to develop.  In 2010, the COGCC received 62 forced pooling applications.  Operators want to avoid the additional time and expense of going through the COGCC process to force pool a mineral owner.   

In negotiating with a landman, it is helpful for a mineral owner to understand the process of forced pooling.  Before an operator can pool an area, the area must be included into a drilling and spacing unit.  This is done through an application with the COGCC.  The COGCC defines a “drilling unit” as the largest amount of acreage that can be efficiently and economically drained by a single well. C.R.S. §34-60-116(2).  Thus, a landowner who only owns a percentage of the minerals under his land may be made part of a drilling unit, regardless of the size of the unit.  Likewise, if a “common source of supply” (i.e. a large reservoir of oil) underlies several parcels of land, all the mineral rights underlying those parcels may become part of a single drilling unit. 

To create a drilling unit, the COGCC defines the boundaries of the “common source of supply” and determines the approximate location of the well in that drilling unit that will efficiently drain the resource.  All of the mineral owners within the proposed drilling unit are given notice (Rule 507(b)) and may require a hearing on the drilling unit by submitting a formal protest to the COGCC. (Rule 509).  However, this is simply a hearing on the underlying geology of the area.  A mineral owner would only be able to object to the size or shape of the drilling unit.  To influence the COGCC decision, the landowner would likely have to offer expert testimony from a geologist.  

Once the drilling unit has been established, an affected mineral owner, who has not leased his minerals, has four different options:  He can choose to sell his minerals, lease his minerals, consent to voluntarily pool his mineral interest with the others and participate (financially) in the drilling operation, or be a “non-consenting” owner and be “force pooled”. 

To “force pool” a non-consenting mineral owner, the industry must apply to the COGCC to get a “force pooling order”.  An unleased mineral owner is considered “non-consenting” if the mineral owner has refused a reasonable offer to lease.  If the order is formally contested by the mineral owner (Rule 509), the COGCC will hold a hearing to determine if the offer to lease was reasonable.  Reasonableness of the offer is determined by comparing the terms offered in the lease to terms accepted by adjacent mineral owners.  Before the hearing, the non-consenting mineral owner should request copies of the operator’s lease agreements with all other mineral owners in the unit.  At the hearing, the non-consenting mineral owner may only present information as to why the lease terms offered were not reasonable (Rule 530(c)) or challenge the operator’s compliance with the rules or statutes.    

If the COGCC issues a force pooling order, there are four consequences for the non-consenting owner;  1) oil and gas operations in that drilling unit are allowed to proceed, 2) the mineral owner will get a 1/8 (12.5%) royalty payment, 3)  the other 7/8 of the mineral interest payments are withheld to pay-off the costs of the well (plus penalties), and 4) if the mineral owner owns 100% of the minerals under a parcel of land, the operator will not be able to locate the well or facilities on that parcel.

A non-consenting mineral owner’s working interest in the well is his proportionate share of mineral rights in the drilling unit.  If the mineral owner had ten (10) acres of mineral rights in a forty-(40) acre drilling unit, his working interest in the well would be 25%.  To obtain a working ownership interest, he would be required to pay 25% of the costs but then would receive 25% of the income. 

Because the non-consenting owner has not paid his (25%) share of the costs, he will not receive his working interest income until those costs are paid.  Instead, the non-consenting owner will only get a 1/8 royalty payment from that working interest.  The other 7/8 income is withheld by the operator until the amount collected equals the non-consenting mineral owner’s proportionate costs of operating the well and off-site equipment, and double the proportionate costs of drilling the well.  Once the costs are paid, then the mineral owner gets his 8/8 proportionate share of the well (in our example, the full 25% working interest share).

Here is an (oversimplified) example of how it works using completely fictional numbers:

·       If the force-pooled mineral owner owns 25% of the minerals in the drilling unit, then that owner would get 1/8 (12.5%) of his 25% share of production proceeds as a royalty.

·       The other 7/8 (87.5%) of the force-pooled mineral owner’s proportionate income goes to pay the mineral owner’s proportionate costs of annual operation and off-site equipment (25%), and double the proportionate costs of drilling the well (50%).

·       For the sake of convenience, let’s say the cost of drilling a well is three-million ($3,000,000), off-site equipment is $100,000, and the cost of annual operations are $100,000/year.

·       The costs that must be recouped by the operator before the mineral owner becomes a part-owner of the well are:

             o   50% of $3,000,000 drilling costs = $1,500,000

             o   25% of $100,000 of off-site equipment = $25,000

             o   25% of $100,000/year in operating costs= $25,000/year

·       If the well generates an average of one million ($1,000,000) in revenue a year, the working interest in our example would be 25% of one million= $250,000 (minus costs). 

·       The royalty payment the mineral owner receives is 1/8 (12.5%) of $250,000 = $31,250/year. 

·       The other 7/8 (87.5%) of the mineral owner’s income would go to pay the costs of the well listed above.  7/8 of $250,000 = $218,750

In this scenario, it would take over seven years to pay the proportionate share of the costs that must be recouped before the non-consenting mineral owner gets their 25% ownership share in the well.  At that point, the well production may have substantially declined.  However, many wells are productive for decades. 

This scenario is, of course, based on completely fictional numbers.  Recently, the costs of drilling wells in the Niobrara have been as high as $6 million.  Yet, if the well is a real producer, like the Jake well in Weld County, it would pay-off in less than one year.  Other wells never pay off. 

In summary,

·       Someone who owns all of the minerals on a large acreage probably will not be force pooled. 

·       But force pooling is a real threat to the small landowner or a landowner who does not own 100% of his minerals. 

·       This threat of force pooling is only carried out when the operator has acquired leases to a majority of the acreage it is planning to develop.  During the early leasing phase, an operator will not force pool a mineral owner. 

·       Mineral owners who are forced pooled will still receive a 12.5% royalty interest—then their full proportional mineral interest once well has paid out double the costs of drilling.

·       If you are forced pooled, it is best to get legal representation to ensure your rights are protected. 

All "Interested Parties" on Extraction's Spacing Applications will receive two blue "Notice of Hearing" documents in the mail (attached).  These notices are letting you know that the Spacing Applications we previously received are being set for hearing and that we have until August 15, 2016 to protest the spacing.  If anyone files a protest they will be able to participate in the pre-hearing conference that same week.    

This is only the spacing application, not the drilling permit, and not the force pooling request which have not even been filed yet.  There is a group reviewing this application.

A full copy of these documents can be found here: https://www.dropbox.com/s/f75i8e9xwaep7sh/SpacingApplicationHearing.PDF?dl=1

For those who didn't receive all of these, copies are available here:  

High West Resources Lease (redacted): https://www.dropbox.com/s/b8vww320grg6m55/High%20West%20Letter_Redacted.pdf?dl=1

Extraction Permit Application 1: https://www.dropbox.com/s/73hoc8uigde16yp/Permit%20App%201.pdf?dl=1

Extraction Permit Application 2: https://www.dropbox.com/s/of4b6m6szjv549g/Permit%20App%202.pdf?dl=1

During the meeting with Extraction on Monday, they requested that anyone with questions contact them directly. This included getting answers to many of the questions that were asked during the meeting as well as any questions or concerns that we may have at any point throughout this process.

Hotline Number: 720.282.4582

Email: info@extractionog.com

Please reach out to Extraction with any questions, concerns, or requests for any additional information that you may need.

The following is a repost of Matt Sura's article about establishing a protective lease. The original article can be found on his website: http://www.mattsuralaw.com/oil-and-gas-fact-sheets

Essential Elements of a Protective Oil and Gas Lease 

Matthew Sura, Oil and Gas Attorney, specializing in representing landowners and mineral owners
(720)563-1866
mattsura.law@gmail.com

Why you should never sign a standard industry lease

For most landowners, the investment in their home and property is one of the largest investments they have. Yet, far too often, landowners threaten that investment by signing a lease or surface use agreement without consulting an oil and gas attorney.

Like any business deal, both parties signing an oil and gas lease are hoping to receive some benefit from the transaction. The landowner (mineral owner) wants to receive maximum return for the extraction of his minerals, the oil and gas company wants to get access to those minerals as cheaply as possible with the least number of restrictions to drilling and development.

The standard 88 lease is the oil and gas companies’ opening offer. It is the minimum they think they can offer without being insulting to the mineral owner. If you do not negotiate for better terms in the lease, you will be leaving money on the table, as well as possibly jeopardizing the value of your land.

Leverage in Negotiating with the Oil and Gas Industry

What the industry does not want landowners to know is that landowners do have significant leverage in these negotiations. If you own your mineral rights, you have something of value that the oil and gas company wants. You can negotiate the bonus payments, royalties, the protections for your land… nearly EVERYTHING IS NEGOTIABLE.

The ways to increase your leverage are: educating yourself about your rights and how much they should pay to access your minerals, joining together with your neighbors to increase the acreage you have in the negotiations, and obtaining legal counsel.

Working with your Neighbors: Landowners with mineral rights have the ability to negotiate fair compensation and protection of their land. Landowners can increase their leverage by banding together with their neighbors to negotiate better compensation and surface protections for their entire neighborhood. More acreage = more leverage.

Legal Counsel: Landowners often feel overwhelmed or helpless when first approached by the industry. Industry representatives can leave the landowner feeling like they have no option but to give the industry access to their minerals, or permission to drill on their land. To have equal footing in these negotiations, it is often helpful to have the assistance of an oil and gas attorney who has experience representing land and mineral owners.

Oil and gas law is a specialized area of the law. An attorney that has experience representing landowners and mineral owners in oil and gas transactions will have a better sense of what fair compensation is for mineral rights in the area and may be able to “shop around” your lease to a number of oil and gas companies to find the best terms. An oil and gas attorney will also know the clauses of the lease that must be removed, or added, to protect you and your property.

Negotiations as a Land and Mineral Owner

When the oil and gas industry believes that there is oil and gas under a property, the mineral owner for that property may be approached by a landman to sell or lease those mineral rights. Landmen are professionals that research mineral ownership and negotiate the purchase or lease of mineral rights from willing owners. Some landmen work for the oil and gas operators directly, some work for independent subcontractors who will then transfer the leases they negotiate to oil and gas companies for a profit.

Landmen have a code of ethics but experience has shown that it is not always upheld in practice. One questionable tactic that a landman might employ is to attempt to play one mineral owner against another. A landman may tell a mineral owner that the bonus payments and royalty rates they are offering are much higher than they are offering anyone else. A landman may also state that other neighbors have already signed leases. These statements may be untrue and can build mistrust among neighbors. Landmen may also threaten to “force pool” mineral owners who are unwilling to lease or sell their mineral rights. These are often empty threats that are only meant to intimidate mineral owners who do not immediately sign the first lease presented to them.

Selling mineral rights is a dangerous proposition for any landowner. Landowners who sell all of their mineral rights have sold away their ability to be able to place conditions on how the minerals are extracted, and have forfeited their share of any monetary benefit from the resource extraction. A more common approach is to lease the minerals to an oil and gas operator.

The oil and gas landman’s standard industry lease should be rejected outright. The industry’s standard leases and surface use agreements are not specific to the needs of the landowner and are written to protect the industry, not the landowner.

A Protective Lease

A “protective lease” is one that gives 1) fair compensation for access to your minerals, 2) fair lease terms, and 3) protection of your land through a surface use agreement. Below is a list of clauses in a standard lease as well as other clauses that you will want to consider to make your lease a “protective lease”. This is a partial list of issues a landowner should consider when negotiating a lease. Again, it is extremely helpful to have the assistance of an experienced oil and gas attorney when negotiating a lease.

1)   Fair Compensation

Note: The going rate for bonus payments and royalty rates are very dependent on location and market. If there are some very productive wells nearby, the value of your minerals will rise. If the price of oil continues going up, even marginally-producing areas may be attractive. On the other hand, if a well drilled near your property is a dry hole, then the value of your minerals will drop precipitously. The price of gas is so low that even high-producing wells are being shut in.

STANDARD LEASE PROVISIONS

·      Bonus payments for signing the lease - A bonus payment is money paid as an incentive for simply signing the lease. The bonus payment is set to an amount of money per mineral acre. Bonuses in Colorado over the past few years have ranged from $6,000 / acre to $150 / acre – depending on the location, market price, and number of acres being leased. The more acreage that is being leased— the higher the bonus payment. The money is typically paid within 60 to 90 days of signing a lease.

·      Royalty payments - Royalty payments are a percentage of the production that comes from a well. A mineral owner who has 10 mineral acres within a 100-acre drilling unit has a 10% interest in that well. The lessor will receive a percentage, in the form of a royalty, of that interest. Thus, if the lessor has negotiated a royalty of 18.75% the amount they will receive will be 18.75 % of their 10% interest in the well... or 1.875% of the profits from that well. The royalties are paid without accounting for the costs of drilling the well or most production costs. The lowest rates in Colorado are 15% (on the eastern plains) but can go as high as 20% (1/5).

MODIFICATIONS TO REQUEST

·      Removal of “post-production costs” clause – Lessors need to be careful about provisions in standard leases that permit royalty payments to be reduced based on post-production costs including treating, processing and transporting the gas taken from their property. This provision can reduce the effective royalty rate by 5%. There is usually no post production costs associated with oil production – just gas.

·      Request Independent Audits – Mineral owners with a lot of acreage should attempt to negotiate the right to have a third party confirm the gas company's actual production figures for each well. The lessor should at least have the right to review the oil and gas company's records related to production and operations under the lease.

·      Request payments for pipelines placed over or under your property – An oil and gas company is allowed to place pipelines on a lessors property for gas produced on that land. But if the oil and gas company is attempting to place pipelines over land that serves other mineral interests on adjacent properties, the landowner should be provided additional compensation.

2)   Fair Lease Terms

·      Length of your lease - The length of time that an oil and gas lease remains in effect can have a significant impact on the lessor's ability to negotiate and receive market-rate compensation. The typical oil and gas leases provide for a primary term and a secondary term. The primary term is the initial fixed term (usually three to five years). This is the period of time during which the industry must drill a well. If a well is not drilled during this time, the lease expires. The mineral owner is then free to negotiate a new lease – including a new bonus payment. The secondary term is the period of time the land is in production. This term lasts as long as the wells on the property are still producing in paying quantities.

·      Renewals of your lease, and rates for renewal - There are a variety of ways for a lessee to extend or renew the primary term, whether automatically or through an option. These provisions in the lease must be read and negotiated carefully. The typical renewal provision is one to two years in length and requires repaying the original bonus amount.

·      Warranty Clause - The warranty clause of the oil and gas lease obligates the lessor to defend title to the mineral property leased if it is questioned. The lessor could incur substantial legal expenses in the event of such title disputes. The oil and gas industry employs legions of landmen to search title records. Mineral owners should avoid legal exposure by removing the language or adding a provision that expressly states the mineral owner gives no warranty of title

3)   Surface Protections

The standard industry lease will contain a provision that give the oil and gas operator the right to, “unimpeded ingress and access to the leased lands, and the right to use so much of the surface, and at such locations, as may be necessary or convenient for lessee's oil and gas operations.” TRANSLATION: under the standard industry lease, the operator may use as much of your surface as they wish. To avoid that, you should consider adding the items in a SURFACE USE AGREEMENT that is attached as part of your lease. Once the lease is signed, you have lost much of your leverage to demand protections of your surface. If the operator is unable or unwilling to negotiate a surface use agreement at the time the lease is signed, a provision should be added that states, “Any entry or location of facilities on the surface property is forbidden without permission granted through a separate surface use agreement.”

Here is a sample of issues a landowner may want to include in a surface use agreement:

·      Location of the well(s) – Does the well have to be on your property? Directional or horizontal drilling technologies allow the drilling rig and well pad to be placed several thousand feet away from the 3 underground target the operator wants to produce. If the well or other oil and gas facility must be located on your property, consider the truck traffic, noise, and odors of the industrial facility. Choose a location that will be least obtrusive to yourself, and your neighbors.

·      Multi-well pads –If there will be multiple wells in the area, operators have the ability to co-locate wells on a single well pad – thereby minimizing the impacts to the surface. However, these facilities are larger, and create more air emissions and nuisance (noise, traffic, light) and longer drilling times. If allowed, multiwell pads should be located far away from homes. I recommend at least 2,000 feet.

·      Location of roads and vehicle access – Can the well be drilled near an existing road? Are there places where you would like the industry to build a road?

·      Transportation plans - It may take over 2,000 round trip truck trips to drill a well. Once the well is drilled, the industry monitors the well at least once a week. In some cases, this monitoring can be accomplished remotely through supervisory control and data acquisition (SCADA) systems.

·      Additional equipment and facilities - Will you allow additional production facilities such as oil and gas processing, compressor engines, or temporary worker housing on your property? Will you allow regional pipelines on your land? You should charge extra for regional facilities to be placed on your land.

·      Limiting surface disturbance –How much acreage will you lose access to? Using an existing surface well site location or access road can avoid the impacts of new construction. Operators may be able to reduce the size of the well pad or to limit the width of the access road.

·      Interim reclamation – What will the land look like when they are done? Operators should prepare a plan to control noxious weeds and undesirable species in disturbed areas. When the drilling is complete, the well site should be reduced to the minimum needed to maintain the well. All other areas should be reclaimed with native species or a seed mix recommended by the landowner. It is a good idea to take pictures of the land before the oil and gas company clears the land and moves in equipment.

·      Pits – Will you allow waste or production pits on your property? All pits eventually leak into ground water and should be avoided if at all possible. The best operators have gone to “pitless drilling” systems that use holding tanks rather than pits to hold drilling fluids and flow-back from fracking or produced water.

·      Waste disposal – How will liquid and solid waste be disposed of? Will you allow waste pits or require closed-loop systems? Some operators try to convince landowners to allow them to “land farm” their drilling muds. This is generally a bad idea because even drilling muds approved from such use come out of the hole with naturally occurring petroleum and other drilling products that are toxic to soil.

·      Ground water impacts – Are you on a water well? Collecting and analyzing water and gas samples from existing water wells or springs before and after drilling is now required in most cases.

·      Noise impacts - Will the facility create noise? Most noise can be reduced through the use of electric motors, mufflers, locating or orienting motors or compressors to reduce noise, or installing insulated buildings or sound barriers.

·      Dust impacts –Industry is usually willing to water roads to control dust during drilling operations.

·      Visual impacts – Are there views you would like to protect? Would you prefer that the well is screened behind a berm? Will there be lights during drilling and after the well is drilled?

·      Water rights - Will the operator be using water taken from the property?

·      Fencing –Installing security fencing around wellheads and production equipment can help protect residents or livestock and contain surface impacts to a limited area.

·      Damages – How will the landowner be compensated for damage to the property?

·      Timing – Will the timing of the operations disrupt agricultural uses for the property? Is the area used by wildlife during certain times of the year?

·      Current use – Are there current or future uses of the land that must be accommodated by the operator?

·      Other requirements – Absolutely anything can be added in a surface use agreement. What makes your land special to you? 

For more information: Matt Sura Esq. – mattsura.law @gmail.com / 720-563-1866

Email template letters have been composed to send to our local city council members to ask for an open session to determine the use of the mineral interests held by the City for open space and parks. Please consider sending this letter prior to the city council meeting scheduled for the evening of July 26th.

Ward 3: 
Sam Taylor - staylor@broomfieldcitycouncil.org - 303.931.6477
Bette Erickson - berickson@broomfieldcitycouncil.org - 303.466.3255

• Letter - Email Template to Ward 3 Broomfield Council Members
• Ward 3 Map - ward3.png

Ward 4:
Kevin Kreeger - kkreeger@broomfieldcitycouncil.org - 720.982.3751
Greg Stokes - gstokes@broomfieldcitycouncil.org - 303.466.6710

• Letter - Email Template to Ward 4 Broomfield Council Members
• Ward 4 Map - ward4.png

Ballot Initiatives 75 and 78: 
https://yesforhealthandsafety.org/initiatives/
http://dontfrackthornton.com/

Facebook group:
North Metro Neighbors for Safe Energy Development

Renewable EnergyColorado is 42nd in the nation in use of renewable energy sources, between PA and OK
http://energy.gov/maps/renewable-energy-production-state
We only get 3.11% of our energy from renewables and we are in the top 5 of sunniest states. Renewable sources provide 3.11% of Colorado's energy production, totaling 77,156 billion BTUs. This is 1.02% of total U.S. renewable energy production.

CDOT Study Re Gas and Oil Effect on Transportation
https://www.codot.gov/…/…/april-2015/14-information-only.pdf

Revenue Refund Owed to one oil and gas company
http://denver.cbslocal.com/…/colorado-loses-state-supreme-…/

Colorado has continued to have economy boom in the last year even though the rig count for drilling in Colorado is the lowest in 16 years:
http://www.denverpost.com/…/colorado-rig-count-drops-to-lo…/

Oil and Gas Industry Economic and Fiscal Contributions in Colorado by County, 2014
http://www.denverpost.com/2016/05/06/colorado-rig-count-drops-to-lowest-in-nearly-16-years/