Source: http://www.rrc.state.tx.us/barnettshale/index.php
Timestamp: 2014-04-20 03:10:19
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Barnett Shale for RRC - Content Page
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Click on map to view higher resolution image and to view district contact information Texas Counties with Producing Wells
Click on map to view higher resolution image Texas Counties with Drilling Permits Click on map to view higher resolution image Updated: April 17, 2014
General Information | Statistics | Counties Affected | Tell Us What You Think | Benefits of Natural Gas | Economic Benefits | Jurisdiction Information | FAQs | Editorial Response to the Denton Record-Chronicle
What is the Barnett Shale? The Barnett Shale is a hydrocarbon-producing geological formation of great economic significance to Texas. It consists of sedimentary rocks and the productive part of the formation is estimated to stretch from the city of Dallas west and south, covering 5,000 square miles (13,000 km²) and at least 18 counties. Some experts say that the Barnett Shale is the largest onshore natural gas field in the United States. The field name for the productive portion of the Barnett Shale formation has been designated as the Newark, East Field by the Texas Railroad Commission. Statistics
Drilling Permits Issued - 1993-2014 (PDF) Updated: 04/17/14
Texas Total Natural Gas Production in the Newark, East (Barnett Shale) Field - 1993- 2014 (PDF) Updated: 03/28/14 Production Data Query - provides production data by lease, field, county and operator.
Newark, East (Barnett Shale) Well Count - 1993-2014 (PDF) Updated: 04/17/14 Top of Page History of the Barnett Shale
Top of Page Counties Affected Core Counties
Top of Page Benefits of Natural Gas
Natural gas is a relatively clean burning energy source. Producing additional domestic natural gas may reduce dependence on foreign energy sources. For more information about natural gas, please visit the United States Department of Energy, Natural Gas home page. Economic Benefits Barnett Shale gas production provides economic benefits to individuals, local governmental entities and the state in the form of: bonus payments and royalty income directly to cities, school districts and others; new tax base, various permits and fees payable to local governments, other types of levies such as hotel/motel occupancy taxes; new jobs, new service companies and enhanced economic development. Cleaner burning Texas natural resources. Top of Page What does the Railroad Commission NOT have jurisdiction over and who to contact?
Roads and Traffic: The Railroad Commission does not have jurisdiction over, and exercises no regulatory authority with respect to, private or public roads or road use. Permits issued by the Commission for oil and gas exploration, production, and waste disposal do not limit any independent authority of a municipality, county or other state agencies with respect to road use. For more information concerning local ordinances in the Barnett Shale, please visit the City Ordinances section of the Barnett Shale Energy Education Council web site or for other areas of the state, please visit the Texas Online portal for links to cities and counties in Texas. The Texas Department of Transportation oversees the construction and maintenance of state highways within their jurisdiction. In addition, TXDOT is responsible for issuing access permits to well sites from a roadway on the state highway system. Please review letter for specific access permit requirements. To contact the appropriate district office, please visit the Texas Department of Transportation, Local Information web site. Noise: The Commission has no statutory authority over noise or nuisance related issues. Noise and nuisance related issues would be governed by local ordinances. For more information concerning local ordinances in the Barnett Shale, please visit the City Ordinances section of the Barnett Shale Energy Education Council web site or for other areas of the state, please visit the Texas Online portal for links to cities and counties in Texas. Odors and Air Contaminants: The Railroad Commission does not have regulatory authority over odors or air contaminants. However, for a well within the city limits, the city may enact ordinances regarding odors or other nuisances. In addition, the Texas Commission on Environmental Quality (TCEQ) has jurisdiction over odor and air contaminants. Please see http://www.tceq.state.tx.us/compliance/complaints/odor_complaint.html and http://www.tceq.state.tx.us/implementation/barnettshale/bshale-viewer for more information about how to file odor complaints and obtain information about air contaminants.
Oil and Gas Exploration and Surface Ownership: For general information pertaining to exploration and surface ownership, please visit the Oil and Gas Exploration and Surface Ownership web page. Royalty payments: For general information pertaining to leases and royalties, please visit the General Information Pertaining to Leases and Royalties web page.
Top of Page Top Questions Asked about the Barnett Shale Please click on the question to reveal the answer. 1. What is the minimum drilling distance for well locations and buildings and homes? How close to my house can a well be drilled? The Railroad Commission does not regulate how close a gas well can be drilled to a residential property. However, for a well within the city limits, the city may enact ordinances regarding the proximity to dwellings or other structures. In addition, there is an old law in the Municipal Code, Section 253.005(c), which provides: "A well may not be drilled in the thickly settled part of the municipality or within 200 feet of a private residence."
Commission Rule, 16 Texas Administrative Code (TAC) §3.76 provides that in counties with a population over 400,000 or a population over 140,000 adjacent to a county with a population over 400,000, a developer of the property may obtain Commission approval of a subdivision plan that limits drilling activity to designated drill sites of at least two acres for every 80 acres in the subdivision. You may access this rule directly at: http://info.sos.state.tx.us/pls/pub/readtac$ext.TacPage?sl=R&app=9&p_dir=&p_rloc=&p_tloc=&p_ploc=&pg=1&p_tac=&ti=16&pt=1&ch=3&rl=76 Many mineral leases also include clauses that define how close a well can be drilled to existing structures.
2. Explain why a surface location for horizontal wells is not required to be located on the lease that is being drilled?
Many wells are being drilled horizontally or deviated from offsite locations to reach potential producing horizons that may be beneath city parks, water bodies or housing developments, where a surface location may not be desirable or available. It is not unusual for an operator to obtain surface rights from which to drill a well from an adjacent, more desirable location.
3. Explain why a surface location for horizontal wells can be located on a lease closer to a lease line than the field rules require?
The field rules for a horizontal well regulate specifically the �horizontal drainhole� which is defined in Rule 86 as �That portion of the wellbore drilled in the correlative interval, between the penetration point and the terminus.� The surface location, therefore, can be located anywhere on the lease since this is not considered part of the horizontal drainhole that is within the correlative interval where production may occur. 4. What are the plastic lining requirements for drilling pits and frac water pits?
Railroad Commission rules require an operator to take precautions to prevent pollution of surface and subsurface water, but do not include specific requirements for plastic liners in drilling pits and frac water pits. Many operators use liners in areas where the soil is permeable. Local governments may require the use of lined pits. 5. What is the requirement for reporting production for a well after it has been completed and how do I find out what has been reported? Railroad Commission rules require an operator to file a well completion form with the Commission 30 days after completion of the well or 90 days after completion of the drilling operation, whichever is earliest. (16 TAC §3.16) Production must be filed monthly starting the month after the well begins producing. You can find production information on the RRC website by using the Production Data Query application or the Production Permit Query application. 6. How long does the RRC allow an operator to flare gas from a new well completion until the gas is then connected to the pipeline? Railroad Commission regulations generally allow gas to be released for a period not to exceed ten (10) producing days after initial completion, recompletion, in another field, or workover operations in the same field. However, the Commission may grant exceptions to this rule under certain circumstances. See 16 TAC �3.32
7. What is the typical size, shape and restoration of a drilling location in the Barnett Shale? There are no standard location shapes or sizes; each rig has its own individual �footprint.� Texas law allows an operator the right to use as much of the surface as necessary to explore, drill and produce the minerals from a property. Leases or ordinances may limit the amount of surface that an operator may use and dictate restoration of the site. 8. What can be done about the stormwater runoff? The Commission�s regulations ensure the quality of waters (and land) that could be potentially impacted by an oil and gas operator�s activity. The Commission�s current rules defines �pollution of surface or subsurface water� broadly: "The alteration of the physical, thermal, chemical, or biological quality of, or the contamination of, any surface or subsurface water in the state that renders the water harmful, detrimental, or injurious to humans, animal life, vegetation, or property, or to public health, safety, or welfare, or impairs the usefulness or the public enjoyment of the water for any lawful or reasonable purpose." Please see 16 TAC �3.8.
9. What is law regarding ingress and egress using existing roads? An operator has the right of ingress and egress to the property for the purpose of exploring, drilling and producing the minerals. This right cannot be denied, but it does not require surface owners to allow operators to use existing roads. Should disagreements occur, it is a civil issue that must be pursued through the court system. 10. How will all this activity affect our property values? The Commission does not have any regulatory authority over the impact on property value as a result of drilling activities on your property unless a violation of Commission rules related to the prevention of pollution of usable quality water occurs. However, you should not construe that to mean you do not have legal rights with respect to the quiet enjoyment of your home. You may wish to consult with an attorney in your area to fully understand your rights and remedies available to you.
11. When will they close the pit? Railroad Commission regulations require that the operator empty and close a drilling pit within one year of cessation of drilling activities. The rules require the operator to empty a completion/workover pit within 30 days and to close the pit within 120 days completion/workover operations.
12. What are saltwater disposal wells? To learn more about saltwater disposal wells, please read our FAQ's concerning these types of wells. 13. Who do I contact to file a complaint?
Please contact the appropriate RRC District Office. To locate the District office nearest to you, please go to our interactive map and click on your county. A popup window will appear listing the correct district office.
14. What is the process a drilling company must go through to receive a drilling permit from the RRC? To obtain a drilling permit from the RRC, an operator must have on file an active P-5 in accordance with Statewide Rule 1 (16 TAC §3.1) (SWR 1-Organization Report; Retention of Records; Notice Requirements), which identifies the operator and its officers. (Note: all RRC Rules are available on the Commission's web page at the following link:
http://info.sos.state.tx.us/pls/pub/readtac$ext.ViewTAC?tac_view=4&ti=16&pt=1&ch=3&rl=Y The operator also must have the proper amount of financial assurance on file.
They must submit a Form P-12 (certificate of pooling authority), a plat identifying offset operators, a service list for notice, and any waivers where applicable. Permit Application Fees must be paid based on depth, exceptions and whether or not processing a permit application is expedited. There also are Financial Security Requirements (Statewide Rule 78 (16 TAC §3.78) Fees and Financial Security Requirements).
15. Do they have to show there is likely to be oil or gas in that area? No, however, operators are required to have a legal lease, which gives them the right to extract the minerals, if any, under the surface land. In addition, they also may drill exploratory, test or service wells. These wells all require drilling permits.
16. Is an oil or gas operator required to perform an environmental study or something similar? No, however, operators are required to follow all RRC regulations, which are designed to ensure protection of the public and the environment. As part of this requirement, they must obtain and file a "Water Board Letter" from the Texas Commission on Environmental Quality (TCEQ) that identifies the depth to which fresh water must be protected so the well can be designed to ensure protection of subsurface freshwater.
17. What factors are considered in reviewing a drilling permit application, and who specifically approves this application (district office supervisor? commissioners?)
The RRC checks to make sure all information on the plat matches the information above.
The Drilling Permits Unit administratively approves or denies most regular permits and some exception to rules permits. However, protested permits regarding 16 TAC §3.37, most §3.38 permits, all §3.39 and §3.40 exception permits are set for hearing and will require Commission approval or disapproval. 18. How often are wells inspected?
Wells are not inspected on a set schedule. The frequency of a routine well/lease inspection is based on many factors including the type of well/operation, the location of the well in regard to public areas or sensitive environments, and the compliance record of the operator. Other actions that may trigger an inspection include a third-party complaint, notice to the Commission of a reportable incident (spill, fire, blowout), or notice of a specific job such as a casing job, plugging job, or mechanical integrity-test. During FY 09, the Commission oil and gas inspectors performed 128,270 inspections statewide. 19. What types of things do inspectors look for? This depends on the type of well/operation. In general, the inspector will confirm compliance with all applicable statewide rules with emphasis on rules related to public safety and protection of the environment. For example, an inspection of a lease might include an inspector noting whether proper signs are posted at the lease; is gas being flared illegally; or are there any spills or leaks from equipment or pits.
20. Can the RRC assist with mineral lease agreements?
The Newark East (Barnett Shale) Field is one of the most active drilling targets in the past decade. Activity has expanded to the north in Montague County, to the east in Denton County, to the south in Tarrant County and now is present in 16 counties in North Texas. With respect to entry into lease agreements and actions of individuals, please be advised that the Railroad Commission�s jurisdiction is limited to issues concerning the permitting and production from oil and gas wells in the State of Texas. The Commission has no jurisdiction over property interests or contractual rights, including issues regarding the validity of existing oil, gas and mineral leases and the conduct of individuals attempting to obtain leases. If you have a question concerning the validity of an existing lease or the actions taken by individuals in an attempt to secure the rights to develop the minerals within a particular area, you may wish to consult an attorney with expertise in oil and gas law.
The Commission does maintain records regarding the reported production and disposition of all oil and gas produced from wells in the State. This information may be helpful in determining your interests and any development in the area surrounding your property. Additionally, the Commission also maintains records regarding the permitting of wells. These records include plats and other documents designating the acreage in a pooled unit. These records are required to obtain a drilling permit and for production after a well is completed. If you have the RRC Identification Number for a well (either a five digit number for oil wells or a six digit number for gas wells) you can obtain all reported production information from January 1993 to present and can obtain access to the permitting records at the Commission's website http://www.rrc.state.tx.us. For production information, please use the Commission's Production Data Query application to get access to the on-line database for these records. For drilling permit information, please use the Commission's Drilling Permit application to get access to the on-line database for these records.
21. I have heard about radiation issues associated with oil and gas activities. What are the issues and risks?
Subsurface formations may contain low levels of radioactive materials such as uranium and thorium and their daughter products, radium 226 and radium 228. These materials, called Naturally Occurring Radioactive Materials or NORM, can be brought to the surface in the formation water that is produced in conjunction with oil and gas operations. NORM in these produced waters typically consists of the radionuclides, radium 226 and 228. In addition, radon gas, a radium daughter, may be found in produced natural gas. Because the levels typically are so low, the NORM in produced waters and natural gas is not a problem in Texas unless it becomes concentrated in some manner. Through temperature and pressure changes that occur in the course of oil and gas production operations, radium 226 and 228 found in produced waters may co-precipitate with barium sulfate scale in well tubulars and surface equipment. Concentrations of radium 226 and 228 may also occur in sludge that accumulates in oilfield pits and tanks. These solids become sources of oil and gas NORM waste. In gas processing activities, NORM generally occurs as radon gas in the natural gas stream. Radon decays to Lead-210, then to Bismuth-210, Polonium-210, and finally to stable Lead-206. Radon decay elements occur as a film on the inner surface of inlet lines, treating units, pumps, and valves principally associated with propylene, ethane, and propane processing streams. The highest risk of exposure to oil and gas NORM is to workers employed to cut and ream oilfield pipe, remove solids from tanks and pits, and refurbish gas processing equipment.
Regulatory programs for NORM are administered by both the Texas Department of State Health Services (DSHS) and the Railroad Commission (RRC). The DSHS regulates all activities, except disposal, involving management of NORM and NORM containing or contaminated materials. This includes jurisdiction over possession, use, transfer, transport, recycling, decontamination of equipment and facilities and/or storage of oil and gas NORM wastes, other than such activities when they occur at the site (e.g., lease, unit, or facility) where disposal of oil and gas NORM waste will occur. The DSHS�s radiological program protects the occupationally exposed as well as the public from unnecessary exposure to radiation. The DSHS regulations establish protection standards and requirements for management of NORM, other than disposal. The rules include exemption criteria for certain NORM containing or contaminated materials. Anyone managing NORM materials above the exemption levels must comply with certain standards. The RRC has jurisdiction over disposal of oil and gas NORM waste and the management of NORM waste at an oil and gas property to facilitate disposal at the site. The RRC�s rules were developed in consultation with the DSHS regarding protection of public health and the environment. The relation of exposure pathways and the health risks relative to those pathways was DSHS�s basis for adopting the regulatory exemption levels. Likewise, the adoption of oil and gas NORM waste disposal options is a result of evaluation of the risk relative to each disposal method.
Each agency is responsible for enforcing its own rules; however agencies do communicate with each other on particular sites or issues as necessary and participate (along with the Texas Commission on Environmental Quality) in quarterly Texas Radiation Advisory Board (TRAB) meetings. For background on oil and gas NORM you may also want to review the following link on our website: http://www.rrc.state.tx.us/environmental/publications/norm/index.php Open AllClose All
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